WHAT IS CLAIMED IS:
1. A method of freating a relatively low peπneability fonnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; confrolling the heat from the one or more heat sources such that an average temperature within at least a majority of the selected section of the foπnation is less than about 375 °C; and producing a mixture from the formation.
2. The method of claim 1, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
3. The method of claim 1 , wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
4. The method of claim 1, wherein the one or more heat sources comprise electrical heaters.
5. The method of claim 1, wherein the one or more heat sources comprise surface burners.
6. The method of claim 1, wherein the one or more heat sources comprise flameless disfributed combustors.
7. The method of claim 1, wherein the one or more heat sources comprise natural distributed combustors.
8. The method of claim 1, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
9. The method of claim 1 , further comprising confrolling a pressure within at least a majority of the selected section of the formation with a valve coupled to at least one of the one or more heat sources.
10. The method of claim 1, further comprising confrolling a pressure within at least a majority of the selected section of the formation with a valve coupled to a production well located in the formation.
11. The method of claim 1, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
12. The method of claim 1, wherein providing heat from the one or more heat sources to at least the portion of foπnation comprises:
heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
13. The method of claim 1, wherein allowing the heat to transfer from the one or more heat sources to the selected section comprises fransfening heat substantially by conduction.
14. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
15. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
16. The method of claim 1, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
17. The method of claim 1, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
18. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
19. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
20. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
21. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
22. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
23. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
24. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
25. The method of claim 1, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, and wherein the hydrogen is greater than about 10 % by volume of the non-condensable component and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
26. The method of claim 1, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
27. The method of claim 1, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
28. The method of claim 1, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
29. The method of claim 1, further comprising confrolling formation conditions such that the produced mixture comprises a partial pressure of H2 within the mixture greater than about 0.5 bars.
30. The method of claim 29, wherein the partial pressure of H2 is measured when the mixture is at a production well.
31. The method of claim 1, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
32. The method of claim 1, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
33. The method of claim 1, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
34. The method of claim 1, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
35. The method of claim 1, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
36. The method of claim 34, wherein at least about 20 heat sources are disposed in the foπnation for each production well.
37. The method of claim 1, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
38. The method of claim 1, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the fonnation to form a repetitive pattern of units.
39. The method of clahn 1, further comprising separating the produced mixture into a gas stream and a liquid sfream.
40. The method of claim 1, further comprising separating the produced mixture into a gas sfream and a liquid stream and separating the liquid sfream into an aqueous sfream and a non-aqueous sfream.
41. The method of claim 1, wherein the produced mixture comprises H2S, the method further comprising separating a portion of the H2S from non-condensable hydrocarbons.
42. The method of claim 1, wherein the produced mixture comprises C02, the method further comprising separating a portion of the C02 from non-condensable hydrocarbons.
43. The method of claim 1, wherein the mixture is produced from a production well, wherein the heating is confrolled such that the mixture can be produced from the formation as a vapor.
44. The method of claim 1, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.
45. The method of claim 1, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the foπnation adjacent to the wellbore, and further comprising heatmg the formation with the heater element to produce the mixture, wherein the mixture comprises a large non-condensable hydrocarbon gas component and H2.
46. The method of claim 1, wherein the minimum pyrolysis temperature is about 270 °C.
47. The method of claim 1, further comprising maintaining the pressure within the formation above about 2.0 bars absolute to inhibit production of fluids having carbon numbers above 25.
48. The method of claim 1, further comprising controlling pressure within the formation in a range from about atmospheric pressure to about 100 bars, as measured at a wellhead of a production well, to confrol an amount of condensable hydrocarbons within the produced mixture, wherein the pressure is reduced to increase production of condensable hydrocarbons, and wherein the pressure is increased to increase production of non-condensable hydrocarbons.
49. The method of clahn 1, further comprising confrolling pressure within the formation in a range from about atmospheric pressure to about 100 bars, as measured at a wellhead of a production well, to control an API gravity of condensable hydrocarbons within the produced mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.
50. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to transfer from at least the portion to a selected section of the formation substantially by conduction of heat; pyrolyzing at least some hydrocarbons within the selected section of the foπnation; and producing a mixture from the formation.
51. The method of claim 50, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
52. The method of claim 50, wherein the one or more heat sources comprise elecfrical heaters.
53. The method of claim 50, wherein the one or more heat sources comprise surface burners.
54. The method of clahn 50, wherein the one or more heat sources comprise flameless disfributed combustors.
55. The method of claim 50, wherein the one or more heat sources comprise natural disfributed combustors.
56. The method of claim 50, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
57. The method of claim 50, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1.0 ° C per day during pyrolysis.
58. The method of claim 50, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability foπnation containing heavy hydrocarbons from the one or more heat sources, wherein the foimation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the foimation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
59. The method of claim 50, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
60. The method of claim 50, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
61. The method of claim 50, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
62. The method of claim 50, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
63.' The method of claim 50, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
64. The method of claim 50, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
65. The method of claim 50, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
66. The method of claim 50, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
67. The method of claim 50, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
68. The method of claim 50, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
69. The method of clahn 50, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
70. The method of claim 50, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
71. The method of claim 50, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
72. The method of claim 50, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
73. The method of clahn 50, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
74. The method of claim 73, wherein the partial pressure of H2 is measured when the mixture is at a production well.
75. The method of claim 50, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
76. The method of claim 50, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
77. The method of claim 50, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
78. The method of claim 50, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
79. The method of claim 50, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the foπnation for each production well.
80. The method of claim 79, wherein at least about 20 heat sources are disposed in the formation for each production well.
81. The method of claim 50, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
82. The method of claim 50, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to foπn a repetitive pattern of units.
83. A method of treating a relatively low permeability foπnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; confrolling the heat from the one or more heat sources such that an average temperature within at least a majority of the selected section of the foπnation is less than about 370 °C such that production of a substantial amount of hydrocarbons having carbon numbers greater than 25 is inhibited; controlling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least 2.0 bars absolute; and producing a mixture from the foπnation, wherein about 0.1 % by weight of the produced mixture to about 15 % by weight of the produced mixture are olefins, and wherein an average carbon number of the produced mixture ranges from 1-25.
84. The method of claim 83, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
85. The method of claim 83, wherein confrolling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
86. The method of claim 83, wherein the one or more heat sources comprise elecfrical heaters.
87. The method of claim 83, wherein the one or more heat sources comprise surface burners.
88. The method of claim 83, wherein the one or more heat sources comprise flameless disfributed combustors.
89. The method of claim 83, wherein the one or more heat sources comprise natural distributed combustors.
90. The method of claim 83, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
91. The method of claim 83 , further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
92. The method of claim 83, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability foπnation containing heavy hydrocarbons from the one or more heat sources, wherem the formation has an average heat capacity (Cv), and wherem the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
93. The method of claim 83, wherein allowing the heat to fransfer comprises transfening heat substantially by conduction.
94. The method of claim 83, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
95. The method of claim 83, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
96. The method of claim 83, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
97. The method of claim 83, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
98. The method of claim 83, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
99. The method of claim 83, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
lOO.The method of claim 83, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
lOl.The method of claim 83, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
102.The method of claim 83, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
103. The method of clahn 83, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
104.The method of claim 83, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
105. The method of claim 83, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
106.The method of claim 83, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
107.The method of claim 106, wherein the partial pressure of H2 is measured when the mixture is at a production well.
108.The method of claim 83, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
109.The method of claim 83, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1 lO.The method of claim 83, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
I ll .The method of claim 83, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the foπnation for each production well.
112.The method of claim 111, wherein at least about 20 heat sources are disposed in the formation for each production well.
113.The method of claim 83, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
114.The method of claim 83, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foπnation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
115. The method of claim 83, further comprising separating the produced mixture into a gas stream and a liquid stream.
116.The method of claim 83, further comprising separating the produced mixture into a gas stream and a liquid sfream and separating the liquid sfream into an aqueous sfream and a non-aqueous stream.
117.The method of claim 83, wherein the produced mixture comprises H2S, the method further comprising separating a portion of the H2S from non-condensable hydrocarbons.
118. The method of claim 83, wherein the produced mixture comprises C02, the method further comprising separating a portion of the C02 from non-condensable hydrocarbons.
119. The method of claim 83, wherein the mixture is produced from a production well, wherein the heating is confrolled such that the mixture can be produced from the formation as a vapor.
120.The method of claim 83, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.
121. The method of claim 83, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the formation adjacent to the wellbore, and further comprising heating the formation with the heater element to produce the mixture, wherein the produced mixture comprise a large non-condensable hydrocarbon gas component and H2.
122.The method of claim 83, wherein the minimum pyrolysis temperature is about 270 °C.
123. The method of claim 83, further comprising maintaining the pressure within the formation above about 2.0 bars absolute to inhibit production of fluids having carbon numbers above 25.
124. The method of claim 83, further comprising confrolling pressure within the formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an amount of condensable fluids within the produced mixture, wherein the pressure is reduced to increase production of condensable fluids, and wherein the pressure is increased to increase production of non-condensable fluids.
125. The method of claim 83, further comprising controlling pressure within the formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to confrol an API gravity of condensable fluids within the produced mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.
126.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the formation; confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute; and producing a mixture from the formation.
127.The method of claim 126, wherein confrolling the pressure comprises confrolling the pressure with a valve coupled to at least one of the one or more heat sources.
128.The method of claim 126, wherein confrolling the pressure comprises controlling the pressure with a valve coupled to a production well located in the formation.
129.The method of claim 126, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
130.The method of claim 126, wherein confrolling foimation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
131.The method of claim 126, wherein the one or more heat sources comprise electrical heaters.
132.The method of claim 126, wherein the one or more heat sources comprise surface burners.
133. The method of claim 126, wherein the one or more heat sources comprise flameless distributed combustors.
134.The method of claim 126, wherein the one or more heat sources comprise natural distributed combustors.
135.The method of clahn 126, further comprising controlling a temperature within at least a majority of the selected section of the foπnation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
136.The method of claim 126, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
137. The method of clahn 126, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (C,,), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foimation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*C *pB wherein w is the heating energy/day, h is an average heating rate of the formation, pB is foimation bulk density, and wherein the heating rate is less than about 10 °C/day.
138.The method of claim 126, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
139.The method of claim 126, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
140.The method of claim 126, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
141. The method of claim 126, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
142.The method of claim 126, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
143. The method of claim 126, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
144.The method of claim 126, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
145. The method of claim 126, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
146.The method of claim 126, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
147.The method of claim 126, wherein the produced mixture comprises condensable hydrocarbons, and wherem less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
148.The method of clahn 126, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
149.The method of claim 126, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
150.The method of claim 126, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
151.The method of claim 126, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
152. The method of claim 126, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
153. The method of claim 152, wherein the partial pressure of H2 is measured when the mixture is at a production well.
154. The method of claim 126, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
155.The method of claim 126, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
156.The method of claim 126, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
157.The method of claim 126, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
158.The method of claim 126, wherein producing the mixture from the formation comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the fonnation for each production well.
159.The method of claim 158, wherein at least about 20 heat sources are disposed in the formation for each production well.
160.A method of freating a relatively low penneability foimation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the foπnation; and confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute; confrolling the heat from the one or more heat sources such that an average temperature within at least a majority of the selected section of the formation is less than about 375 °C; and producing a mixture from the foπnation.
161. The method of claim 159, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
162.The method of claim 159, wherein confrolling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
163. The method of claim 159, wherein the one or more heat sources comprise elecfrical heaters.
164.The method of claim 159, wherein the one or more heat sources comprise surface burners.
165. The method of claim 159, wherein the one or more heat sources comprise flameless disfributed combustors.
166.The method of claim 159, wherein the one or more heat sources comprise natural distributed combustors.
167. The method of claim 159, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the fonnation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
168.The method of claim 159, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
169.The method of claim 159, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherehi heating energy/day provided to the volume is equal to or less than Pwr, wherehi Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
170.The method of claim 159, wherein allowing the heat to fransfer comprises transfening heat substantially by conduction.
171. The method of claim 159, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
172.The method of claim 159, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
173. The method of claim 159, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
174.The method of claim 159, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
175.The method of claim 159, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
176.The method of claim 159, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
177. The method of claim 159, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
178. The method of claim 159, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
179.The method of claim 159, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
180. The method of claim 159, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
181. The method of claim 159, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
182.The method of claim 159, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
183. The method of claim 159, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
184.The method of clahn 159, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
185.The method of claim 159, wherein controlling the heat further comprises confrolling the heat such that coke production is inhibited.
186.The method of claim 159, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
187.The method of claim 186, wherein the partial pressure of H2 is measured when the mixture is at a production well.
188. The method of claim 159, further comprising altering the pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
189.The method of claim 159, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
190.The method of claim 159, further comprising:
providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
191. The method of claim 159, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
192.The method of claim 159, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the foπnation for each production well.
193. The method of claim 192, wherein at least about 20 heat sources are disposed in the formation for each production well.
194. The method of claim 159, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
195.The method of claim 159, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
196. A method of freating a relatively low permeability foπnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the formation; producing a mixture from the formation, wherein at least a portion of the mixture is produced during the pyrolysis and the mixture moves through the formation in a vapor phase; and maintaining a pressure within at least a majority of the selected section above about 2.0 bars absolute.
197.The method of claim 196, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foπnation.
198. The method of claim 196, wherein confrolling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
199.The method of claim 196, wherein the one or more heat sources comprise electrical heaters.
200. The method of claim 196, wherein the one or more heat sources comprise surface burners.
201. The method of claim 196, wherein the one or more heat sources comprise flameless disfributed combustors.
202,The method of claim 196, wherein the one or more heat sources comprise natural disfributed combustors.
203.The method of claim 196, further comprising controlling the pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
204.The method of claim 196, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
205.The method of claim 196, wherein providing heat from the one or more heat sources to at least the portion of fonnation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherehi the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
206. The method of claim 196, wherein allowing the heat to fransfer comprises ttansfening heat substantially by conduction.
" 207.The method of claim 196, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
208.The method of claim 196, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
209.The method of claim 196, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
210.The method of claim 196, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
211. The method of claim 196, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
212.The method of claim 196, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
213. The method of claim 196, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
214.The method of claim 196, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
215. The method of claim 196, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
216.The method of claim 196, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
217. The method of claim 196, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
218. The method of claim 196, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
219.The method of claim 196, wherem the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
220.The method of claim 196, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
221. The method of claim 196, wherein the pressure is measured at a wellhead of a production well.
222.The method of claim 196, wherein the pressure is measured at a location within a wellbore of the production well.
223. The method of claim 196, wherein the pressure is maintained below about 100 bars absolute.
224.The method of claim 196, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
225.The method of claim 224, wherein the partial pressure of H2 is measured when the mixture is at a production well.
226. The method of claim 196, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
227.The method of clahn 196, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the foimation.
228. The method of claim 196, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
229.The method of claim 196, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
230. The method of claim 196, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
231. The method of claim 230, wherein at least about 20 heat sources are disposed in the formation for each production well.
232.The method of claim 196, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
233. The method of claim 196, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
234.A method of treating a relatively low permeability foπnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the foπnation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; maintaining a pressure within at least a majority of the selected section of the formation above 2.0 bars absolute; and
producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity higher than an API gravity of condensable hydrocarbons in a mixture producible from the formation at the same temperature and at atmospheric pressure.
235,The method of claim 234, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foπnation.
236.The method of claim 234, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
237. The method of claim 234, wherein the one or more heat sources comprise elecfrical heaters.
238.The method of claim 234, wherem the one or more heat sources comprise surface burners.
239.The method of claim 234, wherein the one or more heat sources comprise flameless distributed combustors.
240. The method of claim 234, wherein the one or more heat sources comprise natural distributed combustors.
241. The method of claim 234, further comprising confrolling the pressure and a temperature within at least a majority of the selected section of the fonnation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
242.The method of claim 234, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
243. The method of claim 234, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
244.The method of claim 234, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
245. The method of claim 234, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
246.The method of claim 234, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
247.The method of claim 234, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
248.The method of claim 234, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
249.The method of claim 234, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
250. The method of claim 234, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
251.The method of claim 234, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
252.The method of clahn 234, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
253. The method of claim 234, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
254.The method of claim 234, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
255. The method of claim 234, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
256.The method of claim 234, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
257.The method of claim 234, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
258.The method of claim 234, wherehi the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
259.The method of claim 234, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
260.The method of claim 234, wherein a partial pressure of H2 is measured when the mixture is at a production well.
261. The method of claim 234, further comprising altering a pressure within the foπnation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
262.The method of claim 234, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
263. The method of claim 234, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
264.The method of claim 234, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
265.The method of claim 234, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
266.The method of claim 265, wherein at least about 20 heat sources are disposed in the formation for each production well.
267.The method of claim 234, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
268. The method of claim 234, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
269.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the foπnation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; maintaining a pressure within at least a majority of the selected section of the formation to above 2.0 bars absolute; and producing a fluid from the formation, wherein condensable hydrocarbons within the fluid comprise an atomic hydrogen to atomic carbon ratio of greater than about 1J5.
270.The method of claim 269, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
271. The method of claim 269, wherein confrolling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
272.The method of claim 269, wherein the one or more heat sources comprise electrical heaters.
273. The method of claim 269, wherein the one or more heat sources comprise surface burners.
274.The method of claim 269, wherein the one or more heat sources comprise flameless distributed combustors.
275.The method of claim 269, wherein the one or more heat sources comprise natural disfributed combustors.
276.The method of claim 269, further comprising confrolling the pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
277.The method of claim 269, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
278.The method of clahn 269, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB
wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
279.The method of claim 269, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
280.The method of claim 269, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
281. The method of claim 269, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
282.The method of claim 269, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
283.The method of claim 269, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
284.The method of claim 269, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
285. The method of claim 269, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
286.The method of claim 269, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
287.The method of claim 269, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
288.The method of claim 269, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
289. The method of claim 269, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
290.The method of claim 269, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
291. The method of claim 269, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
292. The method of claim 269, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
293. The method of claim 269, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
294.The method of claim 269, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
295. The method of claim 269, wherein a partial pressure of H2 is measured when the mixture is at a production well.
296. The method of claim 269, further comprising altering the pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
291. The method of claim 269, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
298. The method of claim 269, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
299.The method of claim 269, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
300.The method of claim 269, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
301.The method of claim 300, wherein at least about 20 heat sources are disposed in the formation for each production well.
302.The method of claim 269, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
303. The method of claim 269, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the foimation to form a repetitive pattern of units.
304. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; maintaining a pressure within at least a majority of the selected section of the foimation to above 2.0 bars absolute; and producing a mixture from the formation, wherein the produced mixture comprises a higher amount of non- condensable components as compared to non-condensable components producible from the foπnation under the same temperature conditions and at atmospheric pressure.
305. The method of claim 304, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
306.The method of claim 304, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
307. The method of claim 304, wherein the one or more heat sources comprise electrical heaters.
308.The method of claim 304, wherein the one or more heat sources comprise surface burners.
309.The method of claim 304, wherein the one or more heat sources comprise flameless disfributed combustors.
3 lO.The method of claim 304, wherein the one or more heat sources comprise natural distributed combustors.
311.The method of claim 304, further comprising controlling the pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
312.The method of claim 304, furtlier comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
313. The method of claim 304, wherein providing heat from the one or more heat sources to at least the portion of formation comprises:
heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the foπnation, ρB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
314.The method of claim 304, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
315. The method of claim 304, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
316.The method of claim 304, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
317.The method of claim 304, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
318.The method of claim 304, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
319.The method of claim 304, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
320.The method of claim 304, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
321. The method of claim 304, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
322.The method of claim 304, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
323. The method of claim 304, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
324.The method of claim 304, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
325.The method of claim 304, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
326. The method of claim 304, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
327. The method of claim 304, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
328. The method of clahn 304, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
329. The method of claim 304, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
330.The method of claim 304, wherein a partial pressure of H2 is measured when the mixture is at a production well.
331. The method of claim 304, further comprising altering the pressure within the formation to inhibit production of hydrocarbons from the foπnation having carbon numbers greater than about 25.
332.The method of claim 304, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
333. The method of claim 304, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
334.The method of claim 304, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
335. The method of claim 334, wherein at least about 20 heat sources are disposed in the formation for each production well.
336. The method of claim 304, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
337.The method of claim 304, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
338. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation such that superhnposed heat from the one or more heat sources pyrolyzes at least about 20 % by weight of hydrocarbons within the selected section of the formation; and producing a mixture from the foπnation.
339. The method of claim 338, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
340.The method of claim 338, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
341.The method of claim 338, wherein the one or more heat sources comprise electrical heaters.
342.The method of claim 338, wherein the one or more heat sources comprise surface burners.
343. The method of claim 338, wherein the one or more heat sources comprise flameless distributed combustors.
344.The method of claim 338, wherein the one or more heat sources comprise natural distributed combustors.
345.The method of claim 338, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
346.The method of claim 338, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
347. The method of claim 338, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the fonnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the foimation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
348.The method of claim 338, wherein allowing the heat to fransfer comprises transferring heat substantially by conduction.
349. The method of claim 338, wherein providing heat from the one or more heat sources comprises heating the selected foπnation such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °C).
350.The method of claim 338, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
351. The method of claim 338, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
352.The method of claim 338, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
353. The method of claim 338, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
354.The method of claim 338, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
355.The method of claim 338, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
356.The method of claim 338, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
357.The method of claim 338, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
358.The method of claim 338, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
359. The method of claim 338, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
360.The method of claim 338, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
361.The method of claim 338, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
362.The method of claim 338, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
363.The method of claim 338, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
364.The method of claim 338, further comprising controlling a pressure within at least a majority of the selected section of the foimation, wherein the controlled pressure is at least about 2.0 bars absolute.
365. The method of claim 338, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
366.The method of claim 338, wherein a partial pressure of H2 is measured when the mixture is at a production well.
367.The method of claim 338, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
368.The method of claim 338, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
369.The method of claim 338, further comprising:
providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
370.The method of claim 338, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
371.The method of claim 338, wherehi allowing the heat to fransfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
372.The method of claim 338, wherein allowing the heat to fransfer comprises substantially uniformly increasing a permeability of a majority of the selected section.
373. The method of claim 338, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
374.The method of claim 373, wherein at least about 20 heat sources are disposed in the formation for each production well.
375.The method of claim 338, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
376.The method of claim 338, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
377. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more -heat sources to a selected section of the formation such that superimposed heat from the one or more heat sources pyrolyzes at least about 20 % of hydrocarbons within the selected section of the formation; and producing a mixture from the formation, wherem the mixture comprises a condensable component having an API gravity of at least about 25°.
378. The method of claim 377, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
379. The method of claim 377, wherein controlling foimation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
380.The method of claim 377, wherein the one or more heat sources comprise elecfrical heaters.
381. The method of claim 377, wherein the one or more heat sources comprise surface burners.
382. The method of claim 377, wherein the one or more heat sources comprise flameless distributed combustors.
383. The method of claim 377, wherein the one or more heat sources comprise natural distributed combustors.
384. The method of claim 377, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the fonnation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
385. The method of claim 377, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
386. The method of claim 377, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
387. The method of claim 377, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
388. The method of claim 377, wherein providing heat from the one or more heat sources comprises heating the selected section such that a theπnal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °C).
389.The method of claim 377, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
390.The method of claim 377, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
391. The method of claim 377, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
392.The method of claim 377, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
393.The method of claim 377, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
394.The method of claim 377, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
395. The method of claim 377, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
396.The method of clahn 377, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
397.The method of claim 377, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
398.The method of claim 377, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
399.The method of claim 377, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
400.The method of claim 377, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
401.The method of claim 377, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
402.The method of claim 377, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
403. The method of claim 377, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
404.The method of claim 377, wherein a partial pressure of H2 is measured when the mixture is at a production well.
405. The method of claim 377, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
406.The method of claim 377, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
407.The method of claim 377, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
408.The method of claim 377, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
409.The method of claim 377, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
410.The method of claim 377, wherein allowing the heat to fransfer comprises substantially uniformly increasing a permeability of a majority of the selected section.
41 l.The method of claim 377, wherem producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
412.The method of claim 411, wherein at least about 20 heat sources are disposed in the formation for each production well.
413. The method of claim 377, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
414.The method of claim 377, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
415. A method of freating a layer of a relatively low penneability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the layer, wherein the one or more heat sources are positioned proximate an edge of the layer; allowing the heat to transfer from the one or more heat sources to a selected section of the layer such that superimposed heat from the one or more heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation; and producing a mixture from the formation.
416.The method of claim 415, wherein the one or more heat sources are laterally spaced from a center of the layer.
417.The method of claim 415, wherein the one or more heat sources are positioned in a staggered line.
418. The method of claim 415, wherein the one or more heat sources positioned proximate the edge of the layer can increase an amount of hydrocarbons produced per unit of energy input to the one or more heat sources.
419. The method of claim 415, wherein the one or more heat sources positioned proximate the edge of the layer can increase the volume of foπnation undergoing pyrolysis per unit of energy input to the one or more heat sources.
420. The method of claim 415, wherein the one or more heat sources comprise elecfrical heaters.
421. The method of claim 415, wherein the one or more heat sources comprise surface burners.
422.The method of claim 415, wherein the one or more heat sources comprise flameless disfributed combustors.
423. The method of claim 415, wherein the one or more heat sources comprise natural disfributed combustors.
424.The method of claim 415, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
425.The method of claim 415, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1.0 ° C per day during pyrolysis.
426. The method of claim 415, wherein providing heat from the one or more heat sources to at least the portion of the layer comprises: heating a selected volume (V) of the relatively low peπneability formation-containing heavy hydrocarbons from the one or more heat sources, wherein the foπnation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
427. The method of claim 415, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
428.The method of claim 415, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
429.The method of claim 415, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
430.The method of claim 415, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
43 l.The method of claim 415, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
432. The method of claim 415, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
433.The method of claim 415, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
434.The method of claim 415, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
435. The method of claim 415, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
436.The method of claim 415, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
437. The method of claim 415, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
438.The method of claim 415, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
439.The method of claim 415, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
440.The method of claim 415, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
441. The method of clahn 415, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherehi a partial pressure of H2 within the mixture is greater than about 0.5 bars.
442.The method of claim 441, wherein the partial pressure of H2 is measured when the mixture is at a production well.
443. The method of claim 415, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the foπnation having carbon numbers greater than about 25.
444.The method of claim 415, further comprising confrolling formation conditions, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
445.The method of claim 415, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
446. The method of claim 415, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
447.The method of claim 415, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the foπnation for each production well.
448.The method of claim 447, wherein at least about 20 heat sources are disposed in the formation for each production well.
449.The method of claim 415, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foπnation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
450.The method of claim 415, further comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
451.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure; and producing a mixture from the formation.
452.The method of claim 451, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foπnation.
453. The method of claim 451, wherein confrolling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
454.The method of claim 451, wherein the one or more heat sources comprise electrical heaters.
455.The method of clahn 451, wherein the one or more heat sources comprise surface burners.
456.The method of claim 451, wherein the one or more heat sources comprise flameless disfributed combustors.
457.The method of claim 451, wherein the one or more heat sources comprise natural disfributed combustors.
458.The method of claim 451, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
459. The method of claim 451, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low peπneability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
460.The method of claim 451, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
461.The method of claim 451 , wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
462.The method of claim 451, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
463.The method of claim 451, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
464.The method of claim 451, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
465.The method of claim 451 , wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
466. The method of claim 451, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
467.The method of claim 451, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
468.The method of claim 451, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
469.The method of claim 451, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
470.The method of claim 451 , wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
47 l.The method of claim 451, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
472.The method of claim 451, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
473. The method of claim 451, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
474.The method of clahn 451, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
475. The method of claim 451, wherein the controlled pressure is at least about 2.0 bars absolute.
476.The method of claim 451, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
477.The method of claim 451, wherein a partial pressure of H2 is measured when the mixture is at a production well.
478.The method of claim 451, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
479.The method of claim 451, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
480.The method of clahn 451, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
481.The method of claim 451, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
482. The method of claim 451 , wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
483. The method of clahn 482, wherein at least about 20 heat sources are disposed in the foπnation for each production well.
484. The method of claim 451, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
485.The method of claim 451, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
486. A method of freating a relatively low penneability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the foπnation to raise an average temperature within the selected section to, or above, a temperature that will pyrolyze hydrocarbons within the selected section; producing a mixture from the formation; and confrolling API gravity of the produced mixture to be greater than about 25 degrees API by confrolling average pressure and average temperature in the selected section such that the average pressure in the selected section is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the selected section:
_ e f-44000 T+ 67]
where/? is measured in psia and Tis measured in ° Kelvin.
487.The method of claim 486, wherein the API gravity of the produced mixture is controlled to be greater than about 30 degrees API, and wherein the equation is:
488.The method of claim 486, wherein the API gravity of the produced mixture is controlled to be greater than about 35 degrees API, and wherein the equation is:
_ [-22000/T+ 38]
489.The method of claim 486, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
490.The method of claim 486, wherein confrolling the average temperature comprises maintaining a temperature in the selected section within a pyrolysis temperature range.
491. The method of clahn 486, wherein the one or more heat sources comprise elecfrical heaters.
492.The method of claim 486, wherein the one or more heat sources comprise surface burners.
493. The method of claim 486, wherein the one or more heat sources comprise flameless distributed combustors.
494.The method of clahn 486, wherein the one or more heat sources comprise natural distributed combustors.
495.The method of claim 486, further comprising confrolling a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
496.The method of claim 486, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
497.The method of claim 486, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low penneability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherehi heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
498.The method of claim 486, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
499.The method of claim 486, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
500.The method of clahn 486, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
501. The method of clahn 486, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
502.The method of claim 486, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
503. The method of claim 486, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
504.The method of claim 486, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
505.The method of claim 486, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
506.The method of claim 486, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
507.The method of claim 486, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
508. The method of claim 486, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
509.The method of claim 486, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
5 lO.The method of claim 486, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
51 l.The method of claim 486, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
512.The method of claim 486, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
513. The method of claim 486, wherein a partial pressure of H2 is measured when the mixture is at a production well.
514.The method of claim 486, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the foπnation having carbon numbers greater than about 25.
515. The method of claim 486, wherein controlling foπnation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
516.The method of claim 486, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
517.The method of clahn 486, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
518. The method of claim 486, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
519.The method of claim 518, wherein at least about 20 heat sources are disposed in the formation for each production well.
520. The method of claim 486, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
521. The method of claim 486, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the foimation to form a repetitive pattern of units.
522.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat to at least a portion of a relatively low permeability foπnation containing heavy hydrocarbons such that a temperature (7) in a substantial part of the heated portion exceeds 270 °C and hydrocarbons are pyrolyzed within the heated portion of the formation;
confrolling a pressure (p) within at least a substantial part of the heated portion of the formation; vthexe pbar> e [<-Λ /τ> ÷B- 6744] ; wherein p is the pressure in bars absolute and T is the temperature in degrees K, and A and B are parameters that are larger than 10 and are selected in relation to the characteristics and composition of the relatively low peπneability formation containing heavy hydrocarbons and on the required olefin content and carbon number of the pyrolyzed hydrocarbon fluids; and producing pyrolyzed hydrocarbon fluids from the heated portion of the formation.
523.The method of claim 522, wherein A is greater than 14000 and B is greater than about 25 and a majority of the produced pyrolyzed hydrocarbon fluids have an average carbon number lower than 25 and comprise less than about 10 % by weight of olefins.
524.The method of claim 522, wherein T is less than about 390 °C, p is greater than about 1.4 bars, A is greater than about 44000, and b is greater than about 67, and a majority of the produced pyrolyzed hydrocarbon fluids have an average carbon number less than 25 and comprise less than 10 % by weight of olefins.
525. The method of claim 522, wherein Tis less than about 390 °C, p is greater than about 2 bars, A is less than about 57000, and b is less than about 83, and a majority of the produced pyrolyzed hydrocarbon fluids have an average carbon number lower than about 21.
526.The method of claim 522, further comprising confrolling the heat such that an average heating rate of the heated portion is less than about 3°C per day during pyrolysis.
527.The method of claim 522, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
528.The method of claim 522, wherein heat is fransfened substantially by conduction from one or more heat sources to the heated portion of the formation.
529.The method of claim 528, wherein the heat sources comprise heaters in which hydrocarbons are either injected into a heaters or released by the relatively low permeability formation containing heavy hydrocarbons adjacent to a
heater by an oxidant injected into the heater in or adjacent to which the combustion occurs and wherein at least part of the produced combustion gases are vented to surface via the heater in which the combustion occurs.
530.The method of clahn 522, further comprising controlling formation conditions to produce a mixture of hydrocarbon fluids and H2, wherein a partial pressure of H2 within the mixture flowing through the formation is greater than 0.5 bars.
53 l.The method of claim 530, further comprising, hydrogenating a portion of the produced pyrolyzed hydrocarbon fluids with at least a portion of the produced hydrogen and heating the fluids with heat from hydrogenation.
532. The method of claim 522, wherein the substantially gaseous pyrolyzed hydrocarbon fluids are produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the hydrocarbon fluids within the wellbore.
533.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the formation to raise an average temperature within the selected section to, or above, a temperature that will pyrolyze hydrocarbons within the selected section; producing a mixture from the foimation; and controlling a weight percentage of olefins of the produced mixture to be less than about 20 % by weight by controlling average pressure and average temperature in the selected section such that the average pressure in the selected section is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the selected section:
_ e [-57000/T+ 83]
where p is measured in psia and Tis measured in ° Kelvin.
534.The method of clahn 533, wherein the weight percentage of olefins of the produced mixture is confrolled to be less than about 10 % by weight, and wherein the equation is: p _ e [-16000/7 + 28]
535.The method of claim 533, wherein the weight percentage of olefins of the produced mixture is confrolled to be less than about 5 % by weight, and wherein the equation is: p _ e [-I2000/T÷ 22J
536.The method of claim 533, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
537.The method of claim 533, wherein the one or more heat sources comprise elecfrical heaters.
538.The method of claim 533, wherein the one or more heat sources comprise surface burners.
539.The method of claim 533, wherein the one or more heat sources comprise flameless disfributed combustors.
540.The method of claim 533, wherein the one or more heat sources comprise natural disfributed combustors.
541.The method of claim 533, further comprising confrolling a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
542.The method of claim 541, wherein confrolling an average temperature comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
543. The method of claim 533, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 3.0 °C per day during pyrolysis.
544.The method of claim 533, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
545. The method of claim 533, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the foπnation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
546.The method of claim 533, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
547.The method of claim 533, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
548. The method of claim 533, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
549.The method of claim 533, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
550.The method of claim 533, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
55 l.The method of claim 533, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
552.The method of claim 533, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
553. The method of clahn 533, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
554.The method of claim 533, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
555.The method of claim 533, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
556.The method of claim 533, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
557. The method of claim 533, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
558.The method of claim 533, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
559.The method of clahn 533, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
560.The method of claim 533, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
56 l.The method of claim 533, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
562.The method of claim 533, wherein a partial pressure of H2 is measured when the mixture is at a production well.
563. The method of claim 533, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
564.The method of claim 533, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
565. The method of claim 533, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
566. The method of claim 533, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
567.The method of claim 533, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
568.The method of claim 567, wherein at least about 20 heat sources are disposed in the foimation for each production well.
569. The method of claim 533, further comprising providing heat from three or more heat sources to at least a portion of the fonnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
570.The method of claim 533, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the foπnation to form a repetitive pattern of units.
571.A method of freating a relatively low permeability foπnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation;
allowing the heat to fransfer from the one or more heat sources to a selected section of the formation to raise an average temperature within the selected section to, or above, a temperature that will pyrolyze hydrocarbons within the selected section; producing a mixture from the formation; and controlling hydrocarbons having carbon numbers greater than 20 of the produced mixture to be less than about 20 % by weight by confrolling average pressure and average temperature in the selected section such that the average pressure in the selected section is greater than the pressure (p) set forth in the following equation for an assessed average temperature (7) in the selected section:
_ [-14000,'T + 25]
where p is measured in psia and T is measured in ° Kelvin. •
572.The method of claim 571, wherein the hydrocarbons having carbon numbers greater than 20 of the produced mixture is confrolled to be less than about 15 % by weight, and wherein the equation is: p = e [-18000 T + 32]_
573.The method of claim 571, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
574.The method of claim 571, wherein the one or more heat sources comprise elecfrical heaters.
575. The method of claim 571, wherein the one or more heat sources comprise surface burners.
576.The method of claim 571, wherein the one or more heat sources comprise flameless disfributed combustors.
577.The method of claim 571, wherein the one or more heat sources comprise natural distributed combustors.
578.The method of claim 571, further comprising confrolling a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
579.The method of claim 578, wherein confrolling the temperature comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
580.The method of claim 571, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
581.The method of claim 571, wherein providing heat from the one or more heat sources to at least the portion of formation comprises:
heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherehi heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
582.The method of clahn 571, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
583.The method of claim 571, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
584.The method of claim 571, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
585. The method of claim 571, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
586.The method of claim 571, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
587.The method of claim 571, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
588. The method of claim 571, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
589.The method of claim 571, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
590.The method of claim 571, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
591. The method of clahn 571, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
592. The method of claim 571, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
593. The method of claim 571, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
594.The method of claim 571, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
595.The method of claim 571, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
596.The method of claim 571, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
597.The method of claim 571, wherein a partial pressure of H2 is measured when the mixture is at a production well.
598. The method of claim 571, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
599.The method of claim 571, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
600.The method of claim 571, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method fiirther comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
60 l.The method of claim 571, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the foimation for each production well.
602.The method of claim 601, wherein at least about 20 heat sources are disposed in the formation for each production well.
603. The method of claim 571, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
604.The method of claim 571, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
605.A method of treating a relatively low permeability fonnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the foimation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation to raise an average temperature within the selected section to, or above, a temperature that will pyrolyze hydrocarbons within the selected section; producing a mixture from the formation; and confrolling an atomic hydrogen to carbon ratio of the produced mixture to be greater than about 1.7 by controlling average pressure and average temperature in the selected section such that the average pressure in the selected section is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the selected section:
_ [-38000/T + 61]
where p is measured in psia and Tis measured in ° Kelvin.
606.The method of claim 605, wherem the atomic hydrogen to carbon ratio of the produced mixture is confrolled to be greater than about 1.8, and wherein the equation is:
_ ef-13000 T + 24J_
607.The method of claim 605, wherein the atomic hydrogen to carbon ratio of the produced mixture is controlled to be greater than about 1.9, and wherein the equation is:
608.The method of claim 605, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foπnation.
609.The method of claim 605, wherein the one or more heat sources comprise electrical heaters.
610.The method of claim 605, wherein the one or more heat sources comprise surface burners.
611.The method of claim 605, wherein the one or more heat sources comprise flameless disfributed combustors.
612.The method of claim 605, wherein the one or more heat sources comprise natural distributed combustors.
613. The method of claim 605, further comprising controlling a temperature within at least a majority of the selected section of the foimation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
614.The method of claim 613, wherein confrolling the temperature comprises maintaining a temperature within the ' selected section within a pyrolysis temperature range.
615. The method of claim 605, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
616.The method of claim 605, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
617.The method of claim 605, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
618.The method of claim 605, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
619.The method of claim 605, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
620.The method of claim 605, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
62 l.The method of claim 605, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
622.The method of claim 605, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
623. The method of claim 605, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
624.The method of claim 605, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
625. The method of claim 605, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
626. The method of clahn 605, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
627.The method of claim 605, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
628. The method of claim 605, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
629. The method of claim 605, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
630.The method of claim 605, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
63 l.The method of clahn 605, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
632.The method of claim 605, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
633. The method of claim 605, wherein a partial pressure of H2 is measured when the mixture is at a production well.
634.The method of claim 605, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
635. The method of claim 605, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the foπnation.
636.The method of claim 605, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
637.The method of claim 605, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
638.The method of claim 605, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
639.The method of claim 638, wherein at least about 20 heat sources are disposed in the foimation for each production well.
640. The method of claim 605, further comprising providing heat from three or more heat sources to at least a portion of the foimation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
641.The method of claim 605, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the fonnation to form a repetitive pattern of units.
642.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; controlling a pressure-temperature relationship within at least the selected section of the formation by selected energy input into the one or more heat sources and by pressure release from the selected section through wellbores of the one or more heat sources; and producing a mixture from the formation.
643. The method of claim 642, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
644. The method of claim 642, wherein the one or more heat sources comprise at least two heat sources.
645. The method of claim 642, wherein the one or more heat sources comprise surface burners.
646.The method of claim 642, wherein the one or more heat sources comprise flameless disfributed combustors.
647.The method of claim 642, wherein the one or more heat sources comprise natural disfributed combustors.
648. The method of claim 642, further comprising confrolling the pressure-temperature relationship by confrolling a rate of removal of fluid from the foπnation.
649.The method of claim 642, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
650.The method of claim 642, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability foimation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
65 l.The method of claim 642, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
652. The method of claim 642, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
653. The method of claim 642, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
654.The method of claim 642, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
655. The method of claim 642, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
656. The method of claim 642, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
657.The method of claim 642, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
658.The method of claim 642, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
659.The method of claim 642, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
660.The method of claim 642, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
66 l.The method of claim 642, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
662. The method of claim 642, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
663. The method of claim 642, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
664. The method of claim 642, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
665.The method of claim 642, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
666.The method of claim 642, further comprising controlling a pressure within at least a majority of the selected section of the foimation, wherein the confrolled pressure is at least about 2.0 bars absolute.
667.The method of claim 642, further comprising controlling formation conditions to produce a mixture of hydrocarbon fluids and H2, wherein the partial pressure of H2 within the mixture is greater than about 0.5 bars.
668. The method of claim 642, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
669. The method of claim 642, wherein a partial pressure of H2 is measured when the mixture is at a production well.
670. The method of claim 642, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
671.The method of claim 642, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
672.The method of claim 642, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
673. The method of claim 642, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
674.The method of clahn 642, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
675.The method of clahn 674, wherein at least about 20 heat sources are disposed in the formation for each production well.
676.The method of claim 642, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
677.The method of claim 642, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foπnation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
678.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: heating a selected volume (V) of the relatively low permeability foπnation containing heavy hydrocarbons, wherein foimation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and
wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
679.The method of claim 678, wherein heating a selected volume comprises heating with an elecfrical heater.
680.The method of claim 678, wherein heating a selected volume comprises heating with a surface burner.
68 l.The method of claim 678, wherein heating a selected volume comprises heating with a flameless disfributed combustor.
682.The method of clahn 678, wherein heating a selected volume comprises heating with at least one natural disfributed combustor.
683.The method of claim 678, further comprising controlling a pressure and a temperature within at least a majority of the selected volume of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
684.The method of clahn 678, further comprising controlling the heating such that an average heating rate of the selected volume is less than about 1 °C per day during pyrolysis.
685.The method of claim 678, wherein a value for Cv is determined as an average heat capacity of two or more samples taken from the relatively low permeability foπnation containing heavy hydrocarbons.
686.The method of claim 678, wherein heating the selected volume comprises fransfening heat substantially by conduction.
687.The method of claim 678, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
688.The method of claim 678, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
689.The method of claim 678, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
690.The method of clahn 678, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
691. The method of claim 678, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
692.The method of claim 678, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
693. The method of claim 678, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
694.The method of claim 678, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
695. The method of claim 678, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
696.The method of claim 678, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
697.The method of claim 678, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
698.The method of claim 678, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
699.The method of clahn 678, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
700.The method of claim 678, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer
70 l.The method of claim 678, further comprising confrolling a pressure within at least a majority of the selected volume of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
702.The method of claim 678, further comprising controlling formation conditions to produce a mixture from the formation comprising condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
703. The method of claim 678, wherein a partial pressure of H2 is measured when the mixture is at a production well.
704.The method of clahn 678, further comprising altering a pressure within the foimation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
705.The method of claim 678, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
706.The method of claim 678, further comprising: providing hydrogen (H2) to the heated volume to hydrogenate hydrocarbons within the volume; and heating a portion of the volume with heat from hydrogenation.
707.The method of claim 678, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
708. The method of claim 678, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
709. The method of claim 708, wherein at least about 20 heat sources are disposed in the foπnation for each production well.
710.The method of claim 678, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
71 l.The method of claim 678, further comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
712.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation;
allowing the heat to fransfer from the one or more heat sources to a selected section of the formation to raise an average temperature within the selected section to, or above, a temperature that will pyrolyze hydrocarbons within the selected section; controlling heat output from the one or more heat sources such that an average heating rate of the selected section rises by less than about 3 °C per day when the average temperature of the selected section is at, or above, the temperature that will pyrolyze hydrocarbons within the selected section; and producing a mixture from the formation.
713. The method of claim 712, wherein confrolling heat output comprises: raising the average temperature within the selected section to a first temperature that is at or above a minimum pyrolysis temperature of hydrocarbons within the formation; limiting energy input into the one or more heat sources to inhibit increase in temperature of the selected section; and increasing energy input into the formation to raise an average temperature of the selected section above the ffrst temperature when production of formation fluid declines below a desired production rate.
714.The method of claim 712, wherein controlling heat output comprises: raising the average temperature within the selected section to a first temperature that is at or above a minimum pyrolysis temperature of hydrocarbons within the formation; limiting energy input into the one or more heat sources to inhibit increase in temperature of the selected section; and increasing energy input into the formation to raise an average temperature of the selected section above the ffrst temperature when quality of formation fluid produced from the formation falls below a deshed quality.
715. The method of claim 712, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section.
716.The method of claim 712, wherein the one or more heat sources comprise electrical heaters.
717. The method of claim 712, wherein the one or more heat sources comprise surface burners.
718.The method of claim 712, wherein the one or more heat sources comprise flameless disfributed combustors.
719.The method of claim 712, wherein the one or more heat sources comprise natural distributed combustors.
720. The method of claim 712, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
721.The method of claim 712, wherein the heat is confrolled such that an average heating rate of the selected section is less than about 1.5 °C per day during pyrolysis.
722.The method of claim 712, wherein the heat is controlled such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
723. The method of claim 712, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density.
724.The method of claim 712, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
725. The method of claim 712, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
726.The method of claim 712, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
727.The method of claim 712, wherein the produced mixture comprises condensable hydrocarbons, wherein the condensable hydrocarbons have an olefin content less than about 2.5 % by weight of the condensable hydrocarbons, and wherein the olefin content is greater than about 0.1 % by weight of the condensable hydrocarbons.
728.The method of claim 712, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.
729.The method of clahn 712, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.10 and wherein the ratio of ethene to ethane is greater than about 0.001.
730. The method of claim 712, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.05 and wherein the ratio of ethene to ethane is greater than about 0.001.
731.The method of claim 712, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
732.The method of claim 712, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
733.The method of claim 712, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
734.The method of claim 712, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
735.The method of claim 712, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
736. The method of claim 712, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
737. The method of claim 712, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
738.The method of claim 712, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
739.The method of claim 712, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
740.The method of claim 712, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
741. The method of claim 712, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
742.The method of claim 712, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
743. The method of claim 712, wherein a partial pressure of H2 is measured when the mixture is at a production well.
744.The method of claim 712, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
745. The method of claim 712, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
746.The method of clahn 712, further comprising: providing H2 to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
747.The method of claim 712, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
748. The method of claim 712, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
749. The method of claim 748, wherein at least about 20 heat sources are disposed in the formation for each production well.
750.The method of clahn 712, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
75 l.The method of claim 712, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to foπn a repetitive pattern of units.
752. A method of treating a relatively low peπneability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; to heat a selected section of the formation to an average temperature above about 270 °C; allowing the heat to transfer from the one or more heat sources to the selected section of the formation;
confrolling the heat from the one or more heat sources such that an average heating rate of the selected section is less than about 3 °C per day during pyrolysis; and producing a mixture from the formation.
753.The method of claim 752, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
754.The method of claim 752, wherein the one or more heat sources comprise elecfrical heaters.
755.The method of claim 752, further comprising supplying elecfricity to the elecfrical heaters substantially during non-peak hours.
756. The method of claim 752, wherein the one or more heat sources comprise surface burners.
757. The method of claim 752, wherein the one or more heat sources comprise flameless distributed combustors.
758.The method of claim 752, wherein the one or more heat sources comprise natural distributed combustors.
759.The method of claim 752, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
760.The method of claim 752, wherein the heat is further controlled such that an average heating rate of the selected section is less than about 3 °C/day until production of condensable hydrocarbons substantially ceases.
761. The method of claim 752, wherein the heat is further controlled that an average heating rate of the selected section is less than about 1.5 °C per day during pyrolysis.
762.The method of clahn 752, wherein the heat is further controlled such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
763. The method of claim 752, wherein providing heat from the one or more heat sources to at least the portion of foπnation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*Cv*pB
wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density.
764.The method of claim 752, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
765. The method of claim 752, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
766. The method of claim 752, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
767.The method of claim 752, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
768. The method of claim 752, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.
769. The method of claim 752, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
770. The method of claim 752, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
77 l.The method of claim 752, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
772.The method of claim 752, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
773. The method of claim 752, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
774. The method of clahn 752, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
775. The method of claim 752, wherein the produced mixture comprises condensable hydrocarbons, and wherehi about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
776. The method of claim 752, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
777. The method of claim 752, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
778. The method of claim 752, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
779.The method of claim 752, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
780. The method of claim 752, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
78 l.The method of claim 780, wherein the partial pressure of H2 is measured when the mixture is at a production well.
782.The method of claim 752, further comprising altering a pressure within the fonnation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
783. The method of claim 752, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
784.The method of claim 752, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
785.The method of claim 752, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
786.The method of claim 752, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
787.The method of claim 786, wherein at least about 20 heat sources are disposed in the formation for each production well.
788. The method of clahn 752, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
789.The method of claim 752, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
790.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; producing a mixture from the formation through at least one production well; monitoring a temperature at or in the production well; and confrolling heat input to raise the monitored temperature at a rate of less than about 3 °C per day.
791.The method of claim 790, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
792.The method of claim 790, wherein the one or more heat sources comprise electrical heaters.
793. The method of claim 790, wherein the one or more heat sources comprise surface burners.
794.The method of claim 790, wherein the one or more heat sources comprise flameless disfributed combustors.
795. The method of claim 790, wherein the one or more heat sources comprise natural distributed combustors.
796. The method of claim 790, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
797.The method of claim 790, wherein the heat is confrolled such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
798.The method of claim 790, wherein providing heat from the one or more heat sources to at least the portion of formation comprises:
heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the foπnation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherehi Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density.
799.The method of claim 790, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
800. The method of claim 790, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
801. The method of claim 790, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
802.The method of claim 790, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.
803. The method of claim 790, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
804.The method of claim 790, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
805. The method of claim 790, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
806.The method of claim 790, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
807.The method of claim 790, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
808. The method of claim 790, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
809.The method of claim 790, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
8 lO.The method of claim 790, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volmne of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
81 l.The method of claim 790, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
812.The method of claim 790, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
813. The method of claim 790, further comprising controlling a pressure within at least a maj ority of the selected section of the foimation, wherein the confrolled pressure is at least about 2.0 bars absolute.
814.The method of claim 790, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
815.The method of claim 814, wherein the partial pressure of H2 is measured when the mixture is at a production well.
816.The method of claim 790, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
817.The method of claim 790, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the foπnation.
818. The method of claim 790, further comprising: providing H2 to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
819.The method of claim 790, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
820.The method of claim 790, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the foπnation for each production well.
82 l.The method of claim 820, wherein at least about 20 heat sources are disposed in the formation for each production well.
822.The method of claim 790, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
823. The method of claim 790, further comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
824.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: heating a portion of the formation to a temperature sufficient to support oxidation of hydrocarbons within the portion, wherehi the portion is located substantially adjacent to a wellbore; flowing an oxidant through a conduit positioned within the wellbore to a heat source zone within the portion, wherein the heat source zone supports an oxidation reaction between hydrocarbons and the oxidant; reacting a portion of the oxidant with hydrocarbons to generate heat; and fransfening generated heat substantially by conduction to a pyrolysis zone of the foπnation to pyrolyze at least a portion of the hydrocarbons within the pyrolysis zone.
825. The method of claim 824, wherein heating the portion of the formation comprises raising a temperature of the portion above about 400 °C.
826.The method of claim 824, wherein the conduit comprises critical flow orifices, the method further comprising flowing the oxidant through the critical flow orifices to the heat source zone.
827.The method of claim 824, further comprising removing reaction products from the heat source zone through the wellbore.
828.The method of claim 824, further comprising removing excess oxidant from the heat source zone to inhibit transport of the oxidant to the pyrolysis zone.
829.The method of claim 824, further comprising transporting the oxidant from the conduit to the heat source zone substantially by diffusion.
830.The method of claim 824, further comprising heating the conduit with reaction products being removed through the wellbore.
831.The method of claim 824, wherein the oxidant comprises hydrogen peroxide.
832. The method of claim 824, wherein the oxidant comprises air.
833. The method of claim 824, wherein the oxidant comprises a fluid substantially free of nifrogen.
834.The method of claim 824, further comprising limiting an amount of oxidant to maintain a temperature of the heat source zone less than about 1200 °C.
835. The method of clahn 824, wherein heating the portion of the fonnation comprises electrically heating the formation.
836.The method of claim 824, wherein heating the portion of the formation comprises heating the portion using exhaust gases from a surface burner.
837.The method of claim 824, wherein heating the portion of the formation comprises heating the portion with a flameless disfributed combustor.
838. The method of clahn 824, further comprising confrolling a pressure and a temperature within at least a majority of the pyrolysis zone, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
839. The method of claim 824, further comprising confrolling the heat such that an average heating rate of the pyrolysis zone is less than about 1 °C per day during pyrolysis.
840.The method of claim 824, further comprising confrolling a pressure within at least a majority of the pyrolysis zone of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
84 l.The method of claim 824, further comprising: providing hydrogen (H2) to the pyrolysis zone to hydrogenate hydrocarbons within the pyrolysis zone; and heating a portion of the pyrolysis zone with heat from hydrogenation.
842.The method of claim 824, wherein the wellbore is located along sfrike to reduce pressure differentials along a heated length of the wellbore.
843.The method of claim 824, wherein the wellbore is located along sfrike to increase uniformity of heating along a heated length of the wellbore.
844.The method of claim 824, wherein the wellbore is located along sfrike to increase control of heating along a heated length of the wellbore.
845.A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidant; flowing the oxidant into a conduit, and wherein the conduit is connected such that the oxidant can flow from the conduit to the hydrocarbons; allowing the oxidant and the hydrocarbons to react to produce heat in a heat source zone; allowing heat to transfer from the heat source zone to a pyrolysis zone in the formation to pyrolyze at least a portion of the hydrocarbons within the pyrolysis zone; and removing reaction products such that the reaction products are inhibited from flowing from the heat source zone to the pyrolysis zone.
846.The method of claim 845, wherein heating the portion of the formation comprises raising the temperature of the portion above about 400 °C.
847.The method of claim 845, wherein heating the portion of the formation comprises elecfrically heating the formation.
848.The method of claim 845, wherein heating the portion of the formation comprises heating the portion using exhaust gases from a surface burner.
849.The method of claim 845, wherein the conduit comprises critical flow orifices, the method further comprising flowing the oxidant through the critical flow orifices to the heat source zone.
850.The method of claim 845, wherein the conduit is located within a wellbore, wherein removing reaction products comprises removing reaction products from the heat source zone through the wellbore.
85 l.The method of claim 845, further comprising removing excess oxidant from the heat source zone to inhibit fransport of the oxidant to the pyrolysis zone.
852.The method of claim 845, further comprising ttansporting the oxidant from the conduit to the heat source zone substantially by diffusion.
853. The method of claim 845, wherein the conduit is located within a wellbore, the method further comprising heating the conduit with reaction products being removed through the wellbore to raise a temperature of the oxidant passing through the conduit.
854.The method of claim 845, wherein the oxidant comprises hydrogen peroxide.
855. The method of claim 845, wherein the oxidant comprises air.
856.The method of claim 845, wherein the oxidant comprises a fluid substantially free of nifrogen.
857. The method of claim 845, further comprising limiting an amount of oxidant to maintain a temperature of the heat source zone less than about 1200 °C.
858. The method of claim 845, further comprising limiting an amount of oxidant to maintain a temperature of the heat source zone at a temperature that inhibits production of oxides of nifrogen.
859. The method of claim 845, wherein heating a portion of the foπnation to a temperature sufficient to support oxidation of hydrocarbons within the portion further comprises heating with a flameless distributed combustor.
860.The method of claim 845, further comprising confrolling a pressure and a temperature within at least a majority of the pyrolysis zone of the foπnation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
861. The method of claim 845, further comprising confrolling the heat such that an average heating rate of the pyrolysis zone is less than about 1 °C per day during pyrolysis.
862.The method of claim 845, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
863.The method of claim 845, further comprising confrolling a pressure within at least a majority of the pyrolysis zone, wherein the controlled pressure is at least about 2.0 bars absolute.
864.The method of claim 845, further comprising: providing hydrogen (H2) to the pyrolysis zone to hydrogenate hydrocarbons within the pyrolysis zone; and heating a portion of the pyrolysis zone with heat from hydrogenation.
865. An in situ method for heating a relatively low permeability foπnation containing heavy hydrocarbons, comprising: heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the foimation with an oxidizing fluid, wherein the portion is located substantially adjacent to an opening in the formation; providing the oxidizing fluid to a heat source zone in the formation; allowing the oxidizing gas to react with at least a portion of the hydrocarbons at the heat source zone to generate heat in the heat source zone; and fransfening the generated heat substantially by conduction from the heat source zone to a pyrolysis zone in the formation.
866. The method of claim 865, further comprising transporting the oxidizing fluid through the heat source zone by diffusion.
867.The method of claim 865, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.
868.The method of claim 865, further comprising confrolling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is confrolled.
869.The method of claim 865, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.
870.The method of claim 865, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and fransfening substantial heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.
87 l.The method of claim 865, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
872. The method of claim 865, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the foimation through the conduit and confrolling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.
873. The method of claim 865, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.
874. The method of claim 865, wherein the heat source zone extends radially from the opening a width of less than approximately 0.15 m.
875. The method of claim 865, wherein heating the portion comprises applying electrical cunent to an electric heater disposed within the opening.
876. The method of claim 865, wherein the pyrolysis zone is substantially adjacent to the heat source zone.
877.The method of claim 865, further comprising confrolling a pressure and a temperature within at least a majority of the pyrolysis zone of the fonnation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
878. The method of claim 865, further comprising controlling the heat such that an average heating rate of the pyrolysis zone is less than about 1 °C per day during pyrolysis.
879.The method of claim 865, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
880.The method of claim 865, further comprising controlling a pressure within at least a majority of the pyrolysis zone, wherein the confrolled pressure is at least about 2.0 bars absolute.
881. The method of claim 865, further comprising: providing hydrogen (H2) to the pyrolysis zone to hydrogenate hydrocarbons within the pyrolysis zone; and heating a portion of the pyrolysis zone with heat from hydrogenation.
882.A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; producing a mixture from the formation; and maintaining an average temperature within the selected section above a minimum pyrolysis temperature and below a vaporization temperature of hydrocarbons having carbon numbers greater than 25 to inhibit production of a substantial amount of hydrocarbons having carbon numbers greater than 25 in the mixture.
883. The method of claim 882, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
884.The method of clahn 882, wherein maintaining the average temperature within the selected section comprises maintaining the temperature within a pyrolysis temperature range.
885.The method of clahn 882, wherein the one or more heat sources comprise electrical heaters.
886.The method of claim 882, wherein the one or more heat sources comprise surface burners.
887.The method of claim 882, wherein the one or πiore heat sources comprise flameless distributed combustors.
888. The method of claim 882, wherein the one or more heat sources comprise natural distributed combustors.
889. The method of claim 882, wherein the minimum pyrolysis temperature is greater than about 270 °C.
890.The method of claim 882, wherein the vaporization temperature is less than approximately 450 °C at atmospheric pressure.
891.The method of claim 882, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
892.The method of claim 882, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
893. The method of claim 882, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (C„), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
894.The method of claim 882, wherein allowmg the heat to fransfer comprises fransfening heat substantially by conduction.
895.The method of claim 882, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
896.The method of claim 882, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
897. The method of claim 882, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
898.The method of claim 882, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.
899.The method of claim 882, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
900.The method of claim 882, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
90 l.The method of claim 882, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
902.The method of claim 882, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
903. The method of claim 882, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
904.The method of claim 882, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
905.The method of claim 882, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
906.The method of claim 882, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
907. The method of claim 882, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
908.The method of claim 882, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
909.The method of claim 882, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
910.The method of claim 882, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
91 l.The method of claim 910, wherein the partial pressure of H2 is measured when the mixture is at a production well.
912.The method of claim 882, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
913. The method of claim 882, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
914.The method of claim 882, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
915. The method of claim 882, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the foπnation for each production well.
916.The method of claim 915, wherein at least about 20 heat sources are disposed in the formation for each production well.
917.The method of claim 882, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are Ideated in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
918.The method of claim 882, further comprising providing heat from three or more heat sources to at least a portion of the foimation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
919.A method of treating a relatively low permeability foimation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the foimation; confrolling a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than 25; and producing a mixture from the formation.
920.The method of claim 919, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
921. The method of claim 919, wherein the one or more heat sources comprise elecfrical heaters.
922.The method of claim 919, wherein the one or more heat sources comprise surface burners.
923.The method of claim 919, wherein the one or more heat sources comprise flameless distributed combustors.
924.The method of claim 919, wherein the one or more heat sources comprise natural disfributed combustors.
925.The method of claim 919, further comprising confrolling a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
926.The method of claim 925, wherein controlling the temperature comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
927.The method of claim 919, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
928.The method of claim 919, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low peπneability formation containing heavy hydrocarbons from the one or more heat sources, wherein the fonnation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
929.The method of claim 919, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
930.The method of claim 919, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
93 l.The method of claim 919, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
932.The method of claim 919, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
933. The method of claim 919, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.
934.The method of claim 919, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
935. The method of claim 919, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
936.The method of claim 919, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
937.The method of claim 919, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
938.The method of claim 919, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
939.The method of claim 919, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
940.The method of claim 919, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
94 l.The method of claim 919, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
942.The method of claim 919, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
943. The method of claim 919, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
944.The method of claim 919, further comprising controlling the pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
945. The method of claim 919, further comprising confrolling foimation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
946.The method of claim 945, wherein the partial pressure of H2 is measured when the mixture is at a production well.
947.The method of claim 919, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
948. The method of claim 919, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
949.The method of claim 919, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
950.The method of claim 919, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
951. The method of claim 950, wherein at least about 20 heat sources are disposed in the formation for each production well.
952.The method of claim 919, further comprising providmg heat from three or more heat sources to at least a portion of the foimation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
953. The method of claim 919, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
954.A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the fonnation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
955. The method of claim 954, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
956.The method of claim 954, wherein the one or more heat sources comprise elecfrical heaters.
957.The method of claim 954, wherein the one or more heat sources comprise surface burners.
958.The method of claim 954, wherein the one or more heat sources comprise flameless disfributed combustors.
959.The method of claim 954, wherein the one or more heat sources comprise natural distributed combustors.
960.The method of clahn 954, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the foπnation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
961. The method of claim 954, wherein confrolling the temperature comprises maintaining the temperature within the selected section within a pyrolysis temperature range.
962.The method of claim 954, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
963. The method of claim 954, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, ρB is formation bulk density, and wherein the heathig rate is less than about 10 °C/day.
964.The method of claim 954, wherein allowing the heat to transfer comprises transfening heat substantially by conduction.
965.The method of claim 954, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
966. The method of claim 954, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
967.The method of claim 954, wherehi the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
968. The method of claim 954, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.
969.The method of claim 954, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
970.The method of clahn 954, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
97 l.The method of claim 954, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
972.The method of claim 954, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
973. The method of claim 954, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
974.The method of claim 954, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
975. The method of claim 954, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
976.The method of claim 954, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non- condensable component.
977.The method of claim 954, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
978.The method of claim 954, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
979. The method of claim 954, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
980.The method of claim 954, further comprising confrolling foπnation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
981. The method of claim 980, wherein the partial pressure of H2 is measured when the mixture is at a production well.
982.The method of clahn 954, further comprising altering a pressure within the foπnation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
983. The method of claim 954, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
984.The method of claim 954, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
985.The method of claim 954, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
986.The method of claim 954, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
987.The method of claim 986, wherein at least about 20 heat sources are disposed in the formation for each production well.
988.The method of claim 954, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
989.The method of claim 954, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
990. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: heating a section of the foπnation to a pyrolysis temperature from at least a first heat source, a second heat source and a third heat source, and wherein the first heat source, the second heat source and the third heat source are located along a perimeter of the section; confrolling heat input to the first heat source, the second heat source and the thfrd heat source to limit a heating rate of the section to a rate configured to produce a mixture from the formation with an olefin content of less than about 15% by weight of condensable fluids (on a dry basis) within the produced mixture; and producing the mixture from the foπnation through a production well.
99 l.The method of claim 990, wherem supeφosition of heat form the first heat source, second heat source, and third heat source pyrolyzes a portion of the hydrocarbons within the foπnation to fluids.
992.The method of claim 990, wherein the pyrolysis temperature is between about 270 °C and about 400 °C.
993. The method of claim 990, wherein the first heat source is operated for less than about twenty four hours a day.
994.The method of clahn 990, wherein the first heat source comprises an electrical heater.
995. The method of claim 990, wherein the first heat source comprises a surface burner.
996.The method of claim 990, wherein the first heat source comprises a flameless disfributed combustor.
997.The method of claim 990, wherein the first heat source, second heat source and third heat source are positioned substantially at apexes of an equilateral triangle.
998. The method of claim 990, wherein the production well is located substantially at a geometrical center of the first heat source, second heat source, and third heat source.
999.The method of claim 990, further comprising a fourth heat source, fifth heat source, and sixth heat source located along the perimeter of the section.
1000. The method of claim 999, wherein the heat sources are located substantially at apexes of a regular hexagon.
1001. The method of claim 1000, wherein the production well is located substantially at a center of the hexagon.
1002. The method of claim 990, further comprising confrolling a pressure and a temperature within at least a majority of the section of the foπnation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
1003. The method of claim 990, wherein confrolling the temperature comprises maintaining the temperature within the selected section within a pyrolysis temperature range.
1004. The method of claim 990, further comprising controlling the heat such that an average heating rate of the section is less than about 3 °C per day during pyrolysis.
1005. The method of claim 990, further comprising confrolling the heat such that an average heating rate of the section is less than about 1 °C per day during pyrolysis.
1006. The method of claim 990, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume ( ) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (C„), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1007. The method of claim 990, wherein heating the section of the formation comprises fransfening heat substantially by conduction.
1008. The method of claim 990, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1009. The method of claim 990, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1010. The method of claim 990, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherehi the ratio of ethene to ethane is greater than about 0.001.
1011. The method of claim 990, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1012. The method of claim 990, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1013. The method of claim 990, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1014. The method of claim 990, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1015. The method of claim 990, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1016. The method of claim 990, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1017. The method of claim 990, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1018. The method of claim 990, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1019. The method of claim 990, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1020. The method of claim 990, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1021. The method of claim 990, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1022. The method of claim 990, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1023. The method of claim 1022, wherein the partial pressure of H2 is measured when the mixture is at a production well.
1024. The method of claim 990, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1025. The method of claim 990, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
1026. The method of clahn 990, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1027. The method of claim 990, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprismg hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1028. The method of claim 990, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the foπnation for each production well.
1029. The method of claim 1028, wherein at least about 20 heat sources are disposed in the formation for each production well.
1030. The method of claim 990, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1031. The method of claim 990, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1032. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the fonnation; and producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1033. The method of claim 1032, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foimation.
1034. The method of claim 1032, wherein the one or more heat sources comprise electrical heaters.
1035. The method of claim 1032, wherein the one or more heat sources comprise surface burners.
1036. The method of claim 1032, wherein the one or more heat sources comprise flameless disfributed combustors.
1037. The method of claim 1032, wherein the one or more heat sources comprise natural distributed combustors.
1038. The method of claim 1032, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the foπnation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
1039. The method of clahn 1038, wherein confrolling the temperature comprises maintaining the temperature within the selected section within a pyrolysis temperature range.
1040. The method of claim 1032, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1041. The method of clahn 1032, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1042. The method of claim 1032, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1043. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1044. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1045. The method of claim 1032, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
1046. The method of claim 1032, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.
1047. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1048. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1049. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1050. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1051. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1052. The method of clahn 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1053. The method of claim 1032, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1054. The method of claim 1032, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1055. The method of claim 1032, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1056. The method of claim 1032, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1057. The method of clahn 1032, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1058. The method of claim 1057, wherein the partial pressure of H2 is measured when the mixture is at a production well.
1059. The method of claim 1032, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the foimation having carbon numbers greater than about 25.
1060. The method of claim 1032, wherein controlling foimation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
1061. The method of claim 1032, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1062. The method of claim 1032, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprismg hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1063. The method of claim 1032, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1064. The method of clahn 1063, wherein at least about 20 heat sources are disposed in the formation for each production well.
1065. The method of claim 1032, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1066. The method of claim 1032, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1067. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the foimation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and
producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1068. The method of claim 1067, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1069. The method of claim 1067, wherein the one or more heat sources comprise elecfrical heaters.
1070. The method of claim 1067, wherein the one or more heat sources comprise surface burners.
1071. The method of claim 1067, wherein the one or more heat sources comprise flameless disfributed combustors.
1072. The method of claim 1067, wherein the one or more heat sources comprise natural distributed combustors.
1073. The method of claim 1067, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the foimation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
1074. The method of claim 1073, wherein controlling the temperature comprises maintaining the temperature within the selected section within a pyrolysis temperature range.
1075. The method of claim 1067, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1076. The method of claim 1067, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is foimation bulk density, and wherein the heating rate is less than about 10 °C/day.
1077. The method of claim 1067, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1078. The method of claim 1067, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1079. The method of claim 1067, wherehi the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1080. The method of claim 1067, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
1081. The method of claim 1067, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.
1082. The method of claim 1067, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1083. The method of claim 1067, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1084. The method of claim 1067, wherein the produced mixture comprises condensable hydrocarbons, and wherehi less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1085. The method of claim 1067, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1086. The method of claim 1067, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1087. The method of claim 1067, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1088. The method of claim 1067, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1089. The method of claim 1067, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by
volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1090. The method of claim 1067, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1091. The method of claim 1067, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1092. The method of claim 1067, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1093. The method of clahn 1067, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1094. The method of claim 1093, wherein the partial pressure of H2 is measured when the mixture is at a production well.
1095. The method of claim 1067, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1096. The method of claim 1067, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
1097. The method of claim 1067, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1098. The method of claim 1067, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1099. The method of claim 1067, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1100. The method of claim 1099, wherein at least about 20 heat sources are disposed in the formation for each production well.
1101. The method of claim 1067, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1102. The method of claim 1067, further comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1103. A method of freating a relatively low permeability foπnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the foimation; and producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1104. The method of claim 1103, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1105. The method of claim 1103, wherein the one or more heat sources comprise elecfrical heaters.
1106. The method of claim 1103, wherein the one or more heat sources comprise surface burners.
1107. The method of claim 1103, wherein the one or more heat sources comprise flameless distributed combustors.
1108. The method of claim 1103, wherein the one or more heat sources comprise natural distributed combustors.
1109. The method of clahn 1103, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
1110. The method of claim 1109, wherein controlling the temperature comprises maintaining the temperature within the selected section within a pyrolysis temperature range.
llll. The method of claim 1103, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1112. The method of claim 1103, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the foπnation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1113. The method of claim 1103, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
1114. The method of claim 1103, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1115. The method of claim 1103, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1116. The method of claim 1103, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
1117. The method of claim 1103, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.
1118. The method of claim 1103, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1119. The method of claim 1103, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1120. The method of claim 1103, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1121. The method of claim 1103, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1122. The method of claim 1103, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1123. The method of claim 1103, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1124. The method of claim 1103, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1125. The method of claim 1103, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1126. The method of claim 1103, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1127. The method of claim 1103, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1128. The method of claim 1103, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1129. The method of claim 1128, wherein the partial pressure of H2 is measured when the mixture is at a production well.
1130. The method of clahn 1103, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the foimation having carbon numbers greater than about 25.
1131. The method of clahn 1103, wherein confrolling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
1132. The method of claim 1103, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1133. The method of claim 1103, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1134. The method of claim 1103, wherehi producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1135. The method of claim 1134, wherein at least about 20 heat sources are disposed in the formation for each production well.
1136. The method of claim 1103, further comprising providmg heat from three or more heat sources to at least a portion of the foimation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1137. The method of claim 1103, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1138. A method of freating a relatively low peπneability foπnation containing heavy hydrocarbons in situ, comprising: raising a temperature of a first section of the fonnation with one or more heat sources to a first pyrolysis temperature; heating the first section to an upper pyrolysis temperature, wherein heat is supplied to the first section at a rate configured to inhibit olefin production; producing a first mixture from the foimation, wherein the first mixture comprises condensable hydrocarbons and H2; creating a second mixture from the first mixture, wherein the second mixture comprises a higher concentration of H2 than the first mixture; raising a temperature of a second section of the formation with one or more heat sources to a second pyrolysis temperature; providing a portion of the second mixture to the second section; heatmg the second section to an upper pyrolysis temperature, wherein heat is supplied to the second section at a rate configured to inhibit olefin production; and producing a third mixture from the second section.
1139. The method of clahn 1138, wherein creating the second mixture comprises removing condensable hydrocarbons from the first mixture.
1140. The method of claim 1138, wherein creating the second mixture comprises removing water from the first mixture.
1141. The method of claim 1138, wherein creating the second mixture comprises removing carbon dioxide from the first mixture.
1142. The method of claim 1138, wherein the first pyrolysis temperature is greater than about 270 °C.
1143. The method of claim 1138, wherein the second pyrolysis temperature is greater than about 270 °C.
1144. The method of claim 1138, wherein the upper pyrolysis temperature is about 500 °C.
1145. The method of claim 1138, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the first or second selected section of the formation.
1146. The method of clahn 1138, wherein the one or more heat sources comprise elecfrical heaters.
1147. The method of clahn 1138, wherein the one or more heat sources comprise surface burners.
1148. The method of claim 1138, wherein the one or more heat sources comprise flameless disfributed combustors.
1149. The method of claim 1138, wherein the one or more heat sources comprise natural distributed combustors.
1150. The method of claim 1138, further comprising controlling a pressure and a temperature within at least a majority of the first section and the second section of the fonnation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
1151. The method of claim 1138, further comprising controlling the heat to the first and second sections such that an average heating rate of the first and second sections is less than about 1 °C per day during pyrolysis.
1152. The method of claim 1138, wherein heating the first and the second sections comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heathig pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB
wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is foimation bulk density, and wherein the heating rate is less than about 10 °C/day.
1153. The method of claim 1138, wherein heating the first and second sections comprises fransfening heat substantially by conduction.
1154. The method of claim 1138, wherein the first or third mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1155. The method of claim 1138, wherein the first or third mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1156. The method of claim 1138, wherein the first or third mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1157. The method of claim 1138, wherein the first or third mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1158. The method of claim 1138, wherein the first or third mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1159. The method of claim 1138, wherein the first or thfrd mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1160. The method of claim 1138, wherein the first or third mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1161. The method of claim 1138, wherein the first or third mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1162. The method of claim 1138, wherein the first or third mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1163. The method of claim 1138, wherein the first or third mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1164. The method of claim 1138, wherein the first or third mixture comprises a non-condensable component, and wherein the non-condensable component comprises hydrogen, and wherein the hydrogen is greater than about 10 % by volume of the non-condensable component and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1165. The method of claim 1138, wherein the ffrst or third mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1166. The method of claim 1138, wherein the ffrst or third mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1167. The method of claim 1138, further comprising confrolling a pressure within at least a majority of the first or second sections of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1168. The method of claim 1138, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1169. The method of claim 1168, wherein the partial pressure of H2 within a mixture is measured when the mixture is at a production well.
1170. The method of claim 1138, further comprising altering a pressure within the foimation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1171. The method of claim 1138, further comprising: providing hydrogen (H2) to the first or second section to hydrogenate hydrocarbons within the first or second section; and heating a portion of the first or second section with heat from hydrogenation.
1172. The method of claim 1138, further comprising: producing hydrogen and condensable hydrocarbons from the foimation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1173. The method of claim 1138, wherein producing the first or thfrd mixture comprises producing the first or thfrd mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1174. The method of clahn 1173, wherein at least about 20 heat sources are disposed in the formation for each production well.
1175. The method of claim 1138, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the fonnation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1176. The method of claim 1138, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foπnation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1177. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the foimation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; producing a mixture from the formation; and hydrogenating a portion of the produced mixture with H2 produced from the foπnation.
1178. The method of claim 1177, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foπnation.
1179. The method of claim 1177, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1180. The method of claim 1177, wherein the one or more heat sources comprise electrical heaters.
1181. The method of claim 1177, wherein the one or more heat sources comprise surface burners.
1182. The method of claim 1177, wherein the one or more heat sources comprise flameless disfributed combustors.
1183. The method of claim 1177, wherein the one or more heat sources comprise natural distributed combustors.
1184. The method of claim 1177, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the fonnation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
1185. The method of claim 1177, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1186. The method of claim 1177, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low peπneability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, ρB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1187. The method of claim 1177, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
1188. The method of claim 1177, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1189. The method of claim 1177, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1190. The method of claim 1177, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1191. The method of claim 1177, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1192. The method of claim 1177, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1193. The method of claim 1177, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1194. The method of claim 1177, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1195. The method of clahn 1177, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1196. The method of claim 1177, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1197. The method of claim 1177, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1198. The method of claim 1177, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1199. The method of claim 1177, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1200. The method of claim 1177, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1201. The method of claim 1177, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1202. The method of claim 1177, further comprising confrolling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1203. The method of claim 1177, wherein a partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1204. The method of claim 1177, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1205. The method of claim 1177, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1206. The method of claim 1177, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1207. The method of claim 1206, wherein at least about 20 heat sources are disposed in the formation for each production well.
1208. The method of claim 1177, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1209. The method of claim 1177, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1210. A method of freating a relatively low penneability formation containing heavy hydrocarbons in situ, comprising: heating a first section of the formation; producing H2 from the first section of formation; heating a second section of the formation; and recirculating a portion of the H2 from the first section into the second section of the formation to provide a reducing environment within the second section of the formation.
1211. The method of claim 1210, wherein heating the first section or heating the second section comprises heating with an electrical heater.
1212. The method of claim 1210, wherein heating the first section or heating the second section comprises heating with a surface burner.
1213. The method of claim 1210, wherein heating the ffrst section or heating the second section comprises heating with a flameless disfributed combustor.
1214. The method of claim 1210, wherein heating the first section or heating the second section comprises heating with a natural distributed combustor.
1215. The method of claim 1210, further comprising controlling a pressure and a temperature within at least a majority of the first or second section of the foπnation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
1216. The method of claim 1210, further comprising confrolling the heat such that an average heating rate of the first or second section is less than about 1 °C per day during pyrolysis.
1217. The method of claim 1210, wherein heating the first section or heating the second section further comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1218. The method of claim 1210, wherein heating the first section or heating the second section comprises fransfening heat substantially by conduction.
1219. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1220. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1221. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1222. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1223. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1224. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1225. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1226. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherehi less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1227. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1228. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1229. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1230. The method of clahn 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1231. The method of claim 1210, further comprising producing a mixture from the second section, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1232. The method of claim 1210, further comprising confrolling a pressure within at least a majority of the first or second section of the foπnation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1233. The method of claim 1210, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1234. The method of claim 1233, wherein the partial pressure of H2 within a mixture is measured when the mixture is at a production well.
1235. The method of claim 1210, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1236. The method of claim 1210, further comprising: providing hydrogen (H2) to the second section to hydrogenate hydrocarbons within the section; and heating a portion of the second section with heat from hydrogenation.
1237. The method of claim 1210, further comprising: producing hydrogen and condensable hydrocarbons from the fonnation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1238. The method of claim 1210, further comprising producing a mixture from the formation hi a production well, and wherein at least about 7 heat sources are disposed in the fonnation for each production well.
1239. The method of claim 1238, wherein at least about 20 heat sources are disposed in the formation for each production well.
1240. The method of claim 1210, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1241. The method of claim 1210, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1242. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; producing a mixture from the formation; and confrolling formation conditions such that the mixture produced from the formation comprises condensable hydrocarbons including H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1243. The method of clahn 1242, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foimation.
1244. The method of claim 1242, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
1245. The method of claim 1242, wherein the one or more heat sources comprise electrical heaters.
1246. The method of claim 1242, wherein the one or more heat sources comprise surface burners.
1247. The method of claim 1242, wherein the one or more heat sources comprise flameless distributed combustors.
1248. The method of claim 1242, wherein the one or more heat sources comprise natural distributed combustors.
1249. The method of claim 1242, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the foπnation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
1250. The method of claim 1242, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1251. The method of claim 1242, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low penneability foπnation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1252. The method of claim 1242, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
1253. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1254. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1255. The method of claim 1242, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1256. The method of claim 1242, wherehi the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1257. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1258. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherehi less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1259. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1260. The method of clahn 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1261. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1262. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1263. The method of claim 1242, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1264. The method of claim 1242, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1265. The method of claim 1242, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1266. The method of claim 1242, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1267. The method of claim 1242, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1268. The method of claim 1242, wherein confrolling foπnation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.
1269. The method of clahn 1242, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1270. The method of clahn 1242, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1271. The method of claim 1242, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1272. The method of claim 1271, wherein at least about 20 heat sources are disposed in the formation for each production well.
1273. The method of claim 1242, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1274. The method of claim 1242, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1275. The method of claim 1242, wherein a partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1276. A method of freating a relatively low peπneability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the foπnation; maintaining a pressure of the selected section above atmospheric pressure to increase a partial pressure of H2, as compared to the partial pressure of H2 at atmospheric pressure, in at least a majority of the selected section; and producing a mixture from the foimation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1277. The method of claim 1276, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1278. The method of claim 1276, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1279. The method of claim 1276, wherein the one or more heat sources comprise elecfrical heaters.
1280. The method of claim 1276, wherein the one or more heat sources comprise surface burners.
1281. The method of claim 1276, wherein the one or more heat sources comprise flameless disfributed combustors.
1282. The method of claim 1276, wherein the one or more heat sources comprise natural distributed combustors.
1283. The method of claim 1276, further comprising controlling the pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
1284. The method of claim 1276, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1285. The method of claim 1276, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low peπneability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the foπnation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1286. The method of claim 1276, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1287. The method of claim 1276, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1288. The method of claim 1276, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1289. The method of claim 1276, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1290. The method of claim 1276, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1291. The method of clahn 1276, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1292. The method of claim 1276, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1293. The method of claim 1276, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1294. The method of claim 1276, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1295. The method of claim 1276, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1296. The method of claim 1276, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1297. The method of claim 1276, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1298. The method of claim 1276, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1299. The method of clahn 1276, further comprising controlling the pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1300. The method of claim 1276, further comprising increasing the pressure of the selected section, to an upper limit of about 21 bars absolute, to increase an amount of non-condensable hydrocarbons produced from the formation.
1301. The method of claim 1276, further comprising decreasing pressure of the selected section, to a lower lhnit of about atmospheric pressure, to increase an amount of condensable hydrocarbons produced from the fonnation.
1302. The method of claim 1276, wherein the partial pressure comprises a partial pressure based on properties measured at a production well.
1303. The method of claim 1276, further comprising altering the pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1304. The method of claim 1276, further comprising confrolling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.
1305. The method of claim 1276, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1306. The method of claim 1276, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1307. The method of claim 1276, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1308. The method of claim 1307, wherein at least about 20 heat sources are disposed in the formation for each production well.
1309. The method of claim 1276, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1310. The method of claim 1276, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1311. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the fonnation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; providing H2 to the foπnation to produce a reducing environment in at least some of the fonnation; producing a mixture from the formation.
1312. The method of claim 1311, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1313. The method of claim 1311, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1314. The method of claim 1311, further comprising separating a portion ofhydrogen within the mixture and recirculating the portion into the foπnation.
1315. The method of claim 1311, wherein the one or more heat sources comprise elecfrical heaters.
1316. The method of claim 1311, wherein the one or more heat sources comprise surface burners.
1317. The method of clahn 1311, wherein the one or more heat sources comprise flameless disfributed combustors.
1318. The method of claim 1311, wherein the one or more heat sources comprise natural disfributed combustors.
1319. The method of claim 1311, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
1320. The method of claim 1311, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1321. The method of claim 1311, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (1 of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1322. The method of claim 1311, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
1323. The method of claim 1311, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1324. The method of claim 1311, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1325. The method of claim 1311, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about
0.15.
1326. The method of claim 1311, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1327. The method of claim 1311, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1328. The method of claim 1311, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1329. The method of clahn 1311, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1330. The method of claim 1311, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1331. The method of claim 1311, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1332. The method of claim 1311, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1333. The method of claim 1311, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1334. The method of claim 1311, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1335. The method of claim 1311, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1336. The method of claim 1311, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1337. The method of claim 1311, further comprising confrolling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1338. The method of claim 1311, wherein a partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1339. The method of claim 1311, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1340. The method of claim 1311, wherein providing hydrogen (H2) to the formation further comprises: hydrogenating hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1341. The method of claim 1311, further comprising: producing hydrogen and condensable hydrocarbons from the foπnation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1342. The method of clahn 1311, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1343. The method of claim 1342, wherein at least about 20 heat sources are disposed in the formation for each production well.
1344. The method of clahn 1311, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1345. The method of claim 1311, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1346. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; providing H2 to the selected section to hydrogenate hydrocarbons within the selected section and to heat a portion of the section with heat from the hydrogenation; and confrolling heating of the selected section by controlling amounts of H2 provided to the selected section.
1347. The method of claim 1346, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1348. The method of claim 1346, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1349. The method of claim 1346, wherein the one or more heat sources comprise electrical heaters.
1350. The method of claim 1346, wherein the one or more heat sources comprise surface burners.
1351. The method of claim 1346, wherein the one or more heat sources comprise flameless disfributed combustors.
1352. The method of claim 1346, wherein the one or more heat sources comprise natural disfributed combustors.
1353. The method of claim 1346, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the foπnation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
1354. The method of claim 1346, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1355. The method of claim 1346, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low peπneability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is foimation bulk density, and wherein the heating rate is less than about 10 °C/day.
1356. The method of claim 1346, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1357. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1358. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1359. The method of clahn 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1360. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1361. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1362. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1363. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1364. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1365. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1366. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1367. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1368. The method of claim 1346, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1369. The method of claim 1346, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1370. The method of claim 1346, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1371. The method of claim 1346, further comprising confrolling formation conditions to produce a mixture from the formation, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1372. The method of claim 1371, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1373. The method of claim 1346, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the foimation having carbon numbers greater than about 25.
1374. The method of claim 1346, further comprising confrolling foimation conditions by recirculating a portion ofhydrogen from a produced mixture into the formation.
1375. The method of clahn 1346, further comprising:
producing hydrogen and condensable hydrocarbons from the foimation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1376. The method of claim 1346, further comprising producing a mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1377. The method of claim 1376, wherein at least about 20 heat sources are disposed in the formation for each production well.
1378. The method of claim 1346, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1379. The method of claim 1346, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to foπn a repetitive pattern of units.
1380. An in situ method for producing H2 from a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the formation; and producing a mixture from the formation, wherein a H2 partial pressure within the mixture is greater than about 0.5 bars.
1381. The method of claim 1380, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1382. The method of claim 1380, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1383. The method of claim 1380, wherein the one or more heat sources comprise electrical heaters.
1384. The method of claim 1380, wherein the one or more heat sources comprise surface burners.
1385. The method of claim 1380, wherein the one or more heat sources comprise flameless disfributed combustors.
1386. The method of claim 1380, wherein the one or more heat sources comprise natural distributed combustors.
1387. The method of claim 1380, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
1388. The method of claim 1380, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1389. The method of claim 1380, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability foimation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1390. The method of claim 1380, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1391. The method of claim 1380, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1392. The method of claim 1380, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1393. The method of claim 1380, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1394. The method of claim 1380, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1395. The method of claim 1380, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1396. The method of claim 1380, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1397. The method of claim 1380, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1398. The method of clahn 1380, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1399. The method of claim 1380, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1400. The method of claim 1380, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1401. The method of clahn 1380, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1402. The method of claim 1380, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1403. The method of claim 1380, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1404. The method of claim 1380, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1405. The method of claim 1380, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1406. The method of clahn 1380, further comprising recirculating a portion of the hydrogen within the mixture into the formation.
1407. The method of claim 1380, further comprising condensing a hydrocarbon component from the produced mixture and hydrogenating the condensed hydrocarbons with a portion of the hydrogen.
1408. The method of claim 1380, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1409. The method of clahn 1380, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1410. The method of claim 1409, wherein at least about 20 heat sources are disposed in the formation for each production well.
1411. The method of claim 1380, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1412. The method of claim 1380, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherehi three or more of the heat sources are located in the foimation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the foimation to form a repetitive pattern of units.
1413. The method of claim 1380, wherein a partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1414. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the formation; wherein the selected section has been selected for heating using an atomic hydrogen weight percentage of at least a portion of hydrocarbons in the selected section, and wherein at least the portion of the hydrocarbons in the selected section comprises an atomic hydrogen weight percentage, when measured on a dry, ash-free basis, of greater than about 4.0 %; and producing a mixture from the formation.
1415. The method of claim 1414, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1416. The method of claim 1414, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1417. The method of claim 1414, wherein the one or more heat sources comprise electrical heaters.
1418. The method of claim 1414, wherein the one or more heat sources comprise surface burners.
1419. The method of clahn 1414, wherein the one or more heat sources comprise flameless disfributed combustors.
1420. The method of claim 1414, wherein the one or more heat sources comprise natural distributed combustors.
1421. The method of claim 1414, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the foπnation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
1422. The method of claim 1414, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1423. The method of clahn 1414, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1424. The method of clahn 1414, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1425. The method of claim 1414, wherein providing heat from the one or more heat sources comprises heating the selected section such that a theπnal conductivity of at least a portion of the selected section is greater than about
0.5 W/(m °C).
1426. The method of claim 1414, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1427. The method of claim 1414, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1428. The method of claim 1414, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1429. The method of claim 1414, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1430. The method of claim 1414, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1431. The method of claim 1414, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1432. The method of clahn 1414, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1433. The method of clahn 1414, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1434. The method of clahn 1414, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1435. The method of claim 1414, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1436. The method of claim 1414, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1437. The method of claim 1414, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1438. The method of claim 1414, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1439. The method of claim 1414, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1440. The method of claim 1414, further comprising confrolling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1441. The method of claim 1440, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1442. The method of claim 1414, further comprising altering a pressure within the foπnation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1443. The method of claim 1414, further comprising confrolling formation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1444. The method of claim 1414, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1445. The method of claim 1414, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1446. The method of claim 1414, wherein allowing the heat to fransfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
1447. The method of claim 1414, wherein allowing the heat to fransfer comprises substantially uniformly increasing a permeability of a majority of the selected section.
1448. The method of claim 1414, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1449. The method of claim 1448, wherein at least about 20 heat sources are disposed in the formation for each production well.
1450. The method of claim 1414, further comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1451. The method of claim 1414, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to foπn a repetitive pattern of units.
1452. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the formation; wherein at least some hydrocarbons within the selected section have an initial atomic hydrogen weight percentage of greater than about 4.0 %; and producing a mixture from the formation.
1453. The method of claim 1452, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1454. The method of claim 1452, further comprismg maintaining a temperature within the selected section within a pyrolysis temperature range.
1455. The method of claim 1452, wherein the one or more heat sources comprise elecfrical heaters.
1456. The method of clahn 1452, wherein the one or more heat sources comprise surface burners.
1457. The method of claim 1452, wherein the one or more heat sources comprise flameless disfributed combustors.
1458. The method of claim 1452, wherein the one or more heat sources comprise natural disfributed combustors.
1459. The method of claim 1452, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
1460. The method of claim 1452, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1461. The method of claim 1452, wherein providing heat from the one or more heat sources to at least the portion of formation comprises:
heating a selected volume (V) of the relatively low peπneability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (C„), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the fonnation, ρB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1462. The method of claim 1452, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1463. The method of claim 1452, wherein providing heat from the one or more heat sources comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 /(m °C).
1464. The method of claim 1452, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1465. The method of claim 1452, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1466. The method of claim 1452, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1467. The method of claim 1452, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1468. The method of claim 1452, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1469. The method of claim 1452, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1470. The method of clahn 1452, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1471. The method of claim 1452, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1472. The method of claim 1452, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1473. The method of claim 1452, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1474. The method of claim 1452, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1475. The method of claim 1452, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1476. The method of claim 1452, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1477. The method of claim 1452, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1478. The method of claim 1452, further comprising confrolling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1479. The method of claim 1478, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1480. The method of claim 1452, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1481. The method of claim 1452, further comprising controlling formation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1482. The method of claim 1452, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1483. The method of claim 1452, further comprising: producing hydrogen and condensable hydrocarbons from the foπnation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1484. The method of claim 1452, wherein allowing the heat to fransfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
1485. The method of claim 1452, wherein allowing the heat to fransfer comprises substantially uniformly increasing a peπneability of a majority of the selected section.
1486. The method of claim 1452, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1487. The method of clahn 1486, wherein at least about 20 heat sources are disposed in the formation for each production well.
1488. The method of claim 1452, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1489. The method of claim 1452, further comprising providing heat from three or more heat sources to at least a portion of the foimation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1490. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the foπnation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; wherein the selected section has been selected for heating using a total organic matter weight percentage of at least a portion of the selected section, and wherein at least the portion of the selected section comprises a total organic matter weight percentage, of at least about 5.0 %; and producing a mixture from the formation.
1491. The method of clahn 1490, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1492. The method of claim 1490, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1493. The method of claim 1490, wherein the one or more heat sources comprise electrical heaters.
1494. The method of claim 1490, wherein the one or more heat sources comprise surface burners.
1495. The method of claim 1490, wherein the one or more heat sources comprise flameless distributed combustors.
1496. The method of claim 1490, wherein the one or more heat sources comprise natural disfributed combustors.
1497. The method of claim 1490, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
1498. The method of claim 1490, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1499. The method of claim 1490, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low penneability foπnation containing heavy hydrocarbons from the one or more heat sources, wherein the fonnation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is foπnation bulk density, and wherein the heating rate is less than about 10 °C/day.
1500. The method of clahn 1490, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1501. The method of claim 1490, wherem providing heat from the one or more heat sources comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about
0.5 W/(m °C).
1502. The method of claim 1490, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1503. The method of claim 1490, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1504. The method of claim 1490, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about
0.15.
1505. The method of clahn 1490, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1506. The method of claim 1490, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1507. The method of claim 1490, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1508. The method of claim 1490, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1509. The method of clahn 1490, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1510. The method of claim 1490, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1511. The method of claim 1490, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1512. The method of claim 1490, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volmne of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1513. The method of claim 1490, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1514. The method of claim 1490, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1515. The method of claim 1490, further comprising confrolling a pressure within at least a maj ority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1516. The method of claim 1490, further comprising confrolling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1517. The method of claim 1516, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1518. The method of claim 1490, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1519. The method of claim 1490, further comprising confrolling formation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1520. The method of claim 1490, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1521. The method of claim 1490, further comprising: producing hydrogen and condensable hydrocarbons from the foπnation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1522. The method of claim 1490, wherein allowing the heat to fransfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
The method of claim 1490, wherein allowing the heat to fransfer comprises substantially uniformly increasing a permeability of a majority of the selected section.
1523. The method of claim 1490, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the foπnation for each production well.
1524. The method of claim 1523, wherein at least about 20 heat sources are disposed in the formation for each production well.
1525. The method of claim 1490, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foπnation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1526. The method of claim 1490, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foπnation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1527. A method of treating a relatively low permeability foπnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the fonnation; allowing the heat to fransfer from the one or more heat sources to a selected section of the foimation; wherem at least some hydrocarbons within the selected section have an initial total organic matter weight percentage of at least about 5.0%; and producing a mixture from the foπnation.
1528. The method of claim 1527, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1529. The method of claim 1527, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1530. The method of claim 1527, wherein the one or more heat sources comprise electrical heaters.
1531. The method of claim 1527, wherein the one or more heat sources comprise surface burners.
1532. The method of claim 1527, wherein the one or more heat sources comprise flameless disfributed combustors.
1533. The method of claim 1527, wherein the one or more heat sources comprise natural disfributed combustors.
1534. The method of claim 1527, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
1535. The method of claim 1527, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1536. The method of claim 1527, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the fonnation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the foπnation, ρB is foimation bulk density, and wherein the heating rate is less than about 10 °C/day.
1537. The method of claim 1527, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1538. The method of claim 1527, wherein providing heat from the one or more heat sources comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °C).
1539. The method of claim 1527, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1540. The method of clahn 1527, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1541. The method of claim 1527, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1542. The method of claim 1527, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1543. The method of claim 1527, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1544. The method of claim 1527, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1545. The method of claim 1527, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1546. The method of claim 1527, wherehi the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1547. The method of clahn 1527, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1548. The method of claim 1527, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1549. The method of claim 1527, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1550. The method of claim 1527, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1551. The method of claim 1527, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1552. The method of claim 1527, further comprising controlling a pressure within at least a majority of the selected section of the foimation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1553. The method of claim 1527, further comprising controlling foimation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1554. The method of claim 1553, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1555. The method of claim 1527, further comprising altering a pressure within the foimation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1556. The method of claim 1527, further comprising confrolling formation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1557. The method of claim 1527, further comprising:
providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1558. The method of claim 1527, further comprising: producing hydrogen and condensable hydrocarbons from the fonnation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1559. The method of claim 1527, wherein allowing the heat to fransfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
The method of claim 1527, wherein allowing the heat to fransfer comprises substantially uniformly increasing a penneability of a majority of the selected section.
1561. The method of claim 1527, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1562. The method of claim 1561, wherein at least about 20 heat sources are disposed in the formation for each production well.
1563. The method of claim 1527, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1564. The method of claim 1527, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1565. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; wherein the selected section has been selected for heating using an atomic hydrogen to carbon ratio of at least a portion of hydrocarbons in the selected section, wherein at least a portion of the hydrocarbons in the selected section comprises an atomic hydrogen to carbon ratio greater than about 0.70, and wherein the atomic hydrogen to carbon ratio is less than about 1.65; and producing a mixture from the formation.
1566. The method of claim 1565, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foimation.
1567. The method of claim 1565, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1568. The method of claim 1565, wherein the one or more heat sources comprise elecfrical heaters.
1569. The method of claim 1565, wherein the one or more heat sources comprise surface burners.
1570. The method of claim 1565, wherein the one or more heat sources comprise flameless distributed combustors.
1571. The method of claim 1565, wherein the one or more heat sources comprise natural distributed combustors.
1572. The method of claim 1565, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
1573. The method of claim 1565, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1574. The method of claim 1565, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volmne of the fonnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the foimation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1575. The method of claim 1565, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1576. The method of claim 1565, wherein providing heat from the one or more heat sources comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °C).
1577. The method of clahn 1565, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1578. The method of claim 1565, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1579. The method of claim 1565, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1580. The method of claim 1565, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1581. The method of clahn 1565, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1582. The method of claim 1565, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1583. The method of claim 1565, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1584. The method of claim 1565, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1585. The method of claim 1565, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1586. The method of claim 1565, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1587. The method of claim 1565, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1588. The method of claim 1565, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1589. The method of claim 1565, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1590. The method of clahn 1565, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1591. The method of clahn 1565, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1592. The method of clahn 1591, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1593. The method of claim 1565, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1594. The method of clahn 1565, further comprising controlling formation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1595. The method of claim 1565, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1596. The method of claim 1565, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1597. The method of claim 1565, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
1598. The method of clahn 1565, wherein allowing the heat to transfer comprises substantially uniformly increasing a peπneability of a maj ority of the selected section.
1599. The method of claim 1565, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1600. The method of claim 1599, wherein at least about 20 heat sources are disposed in the formation for each production well.
1601. The method of claim 1565, further comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1602. The method of claim 1565, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1603. A method of freating a relatively low penneability fonnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to a selected section of the formation; allowing the heat to fransfer from the one or more heat sources to the selected section of the formation to pyrolyze hydrocarbons within the selected section; wherein at least some hydrocarbons within the selected section have an initial atomic hydrogen to carbon ratio greater than about 0.70; wherein the initial atomic hydrogen to carbon ration is less than about 1.65; and producing a mixture from the foimation.
1604. The method of claim 1603, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1605. The method of claim 1603, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1606. The method of claim 1603, wherein the one or more heat sources comprise electrical heaters.
1607. The method of claim 1603, wherein the one or more heat sources comprise surface burners.
1608. The method of claim 1603, wherein the one or more heat sources comprise flameless disfributed combustors.
1609. The method of claim 1603, wherein the one or more heat sources comprise natural distributed combustors.
1610. The method of claim 1603, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
1611. The method of claim 1603 , further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1612. The method of claim 1603, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low peπneability fonnation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the foimation, pB is foimation bulk density, and wherein the heating rate is less than about 10 °C/day.
1613. The method of claim 1603, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1614. The method of claim 1603, wherein providing heat from the one or more heat sources comprises heathig the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °C).
1615. The method of claim 1603, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1616. The method of clahn 1603, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1617. The method of claim 1603, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1618. The method of claim 1603 , wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1619. The method of claim 1603, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1620. The method of claim 1603, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1621. The method of claim 1603, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1622. The method of claim 1603, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1623. The method of claim 1603, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1624. The method of claim 1603, wherein the produced mixttire comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1625. The method of claim 1603, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1626. The method of claim 1603, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1627. The method of claim 1603, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1628. The method of claim 1603, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1629. The method of claim 1603, further comprising controlling fonnation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1630. The method of claim 1629, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1631. The method of claim 1603, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1632. The method of claim 1603, further comprising confrolling formation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1633. The method of claim 1603, further comprismg: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1634. The method of claim 1603, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1635. The method of claim 1603, wherein allowing the heat to fransfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
1636. The method of claim 1603, wherein allowing the heat to fransfer comprises substantially uniformly increasing a permeability of a majority of the selected section.
1637. The method of claim 1603, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1638. The method of claim 1637, wherein at least about 20 heat sources are disposed in the foimation for each production well.
1639. The method of claim 1603, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1640. The method of claim 1603, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1641. A method of freating a relatively low permeability foπnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the foπnation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation;
wherein the selected section has been selected for heating using a moisture content in the selected section, and wherein at least a portion of the selected section comprises a moisture content of less than about 15 % by weight; and producing a mixture from the formation.
1642. The method of claim 1641, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the* selected section of the formation.
1643. The method of claim 1641 , further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1644. The method of claim 1641, wherein the one or more heat sources comprise electrical heaters.
1645. The method of claim 1641 , wherein the one or more heat sources comprise surface burners.
1646. The method of claim 1641, wherein the one or more heat sources comprise flameless distributed combustors.
1647. The method of claim 1641, wherein the one or more heat sources comprise natural disfributed combustors.
1648. The method of claim 1641, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
1649. The method of claim 1641, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1650. The method of claim 1641 , wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the foπnation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1651. The method of claim 1641 , wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
1652. The method of claim 1641, wherein providing heat from the one or more heat sources comprises heating the selected section such that a theπnal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °C).
1653. The method of claim 1641, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1654. The method of claim 1641, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1655. The method of claim 1641, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about
0.15.
1656. The method of clahn 1641, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1657. The method of claim 1641, wherein the produced mixture comprises condensable hydrocarbons, and wherehi less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1658. The method of claim 1641, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1659. The method of claim 1641, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1660. The method of claim 1641, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1661. The method of claim 1641 , wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1662. The method of claim 1641, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1663. The method of claim 1641 , wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1664. The method of claim 1641, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1665. The method of claim 1641, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1666. The method of clahn 1641, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1667. The method of claim 1641, further comprismg controlling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1668. The method of claim 1667, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1669. The method of claim 1641, further comprising altering a pressure within the foimation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1670. The method of claim 1641, further comprising controlling foπnation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1671. The method of claim 1641 , further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1672. The method of claim 1641, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1673. The method of claim 1641 , wherein allowing the heat to fransfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
1674. The method of claim 1641, wherein allowing the heat to fransfer further comprises substantially uniformly increasing a peπneability of a majority of the selected section.
1675. The method of claim 1641 , wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1676. The method of claim 1675, wherein at least about 20 heat sources are disposed in the formation for each production well.
1677. The method of claim 1641, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foπnation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1678. The method of claim 1641, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1679. A method of freating a relatively low peπneability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to a selected section of the formation; allowing the heat to ttansfer from the one or more heat sources to the selected section of the foπnation; wherein at least a portion of the selected section has an initial moisture content of less than about 15 % by weight; and producing a mixture from the formation.
1680. The method of claim 1679, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1681. The method of claim 1679, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1682. The method of claim 1679, wherein the one or more heat sources comprise elecfrical heaters.
1683. The method of claim 1679, wherein the one or more heat sources comprise surface burners.
1684. The method of claim 1679, wherein the one or more heat sources comprise flameless disfributed combustors.
1685. The method of claim 1679, wherein the one or more heat sources comprise natural distributed combustors.
1686. The method of claim 1679, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
1687. The method of claim 1679, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1688. The method of claim 1679, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, A is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1689. The method of claim 1679, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1690. The method of claim 1679, wherein providing heat from the one or more heat sources comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about
0.5 W/(m °C).
1691. The method of clahn 1679, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1692. The method of claim 1679, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1693. The method of claim 1679, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about
0.15.
1694. The method of claim 1679, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1695. The method of claim 1679, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1696. The method of claim 1679, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1697. The method of claim 1679, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1698. The method of claim 1679, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1699. The method of claim 1679, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1700. The method of claim 1679, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1701. The method of claim 1679, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1702. The method of claim 1679, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1703. The method of claim 1679, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1704. The method of claim 1679, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1705. The method of claim 1679, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1706. The method of claim 1705, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1707. The method of claim 1679, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1708. The method of claim 1679, further comprising controlling foπnation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1709. The method of claim 1679, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1710. The method of claim 1679, further comprising: producing hydrogen and condensable hydrocarbons from the foπnation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1711. The method of claim 1679, wherein allowing the heat to fransfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
1712. The method of claim 1679, wherein allowing the heat to fransfer further comprises substantially uniformly increasing a permeability of a majority of the selected section.
1713. The method of claim 1679, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1714. The method of clahn 1713, wherein at least about 20 heat sources are disposed in the formation for each production well.
1715. The method of claim 1679, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1716. The method of claim 1679, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1717. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the foπnation; allowing the heat to transfer from the one or more heat sources to a selected section of the foπnation;
wherein the selected section is heated in a reducing environment during at least a portion of the time that the selected section is being heated; and producing a mixture from the formation.
1718. The method of claim 1717, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foπnation.
1719. The method of claim 1717, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1720. The method of claim 1717, wherein the one or more heat sources comprise electrical heaters.
1721. The method of claim 1717, wherein the one or more heat sources comprise surface burners.
1722. The method of claim 1717, wherein the one or more heat sources comprise flameless disfributed combustors.
1723. The method of claim 1717, wherein the one or more heat sources comprise natural disfributed combustors.
1724. The method of claim 1717, further comprising confrolling a pressure and a temperature withhi at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
1725. The method of claim 1717, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1726. The method of claim 1717, wherein providing heat from the one or more heat sources to at least the portion of foimation comprises: heating a selected volume ( V) of the relatively low permeability foπnation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1727. The method of claim 1717, wherein allowing the heat to ttansfer comprises fransfening heat substantially by conduction.
1728. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1729. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1730. The method of claim 1717, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1731. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1732. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1733. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1734. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1735. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1736. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1737. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1738. The method of claim 1717, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1739. The method of claim 1717, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1740. The method of claim 1717, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1741. The method of claim 1717, further comprising controlling a pressure within at least a maj ority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1742. The method of claim 1717, further comprising confrolling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1743. The method of claim 1742, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1744. The method of claim 1717, further comprising altering a pressure within the fonnation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1745. The method of claim 1717, further comprising confrolling formation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1746. The method of claim 1717, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1747. The method of claim 1717, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1748. The method of claim 1717, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the foπnation for each production well.
1749. The method of claim 1748, wherein at least about 20 heat sources are disposed in the formation for each production well.
1750. The method of claim 1717, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1751. The method of claim 1717, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the foimation to form a repetitive pattern of units.
1752. A method of freating a relatively low permeability foimation containing heavy hydrocarbons in situ, comprising: heating a first section of the formation to produce a mixture from the foπnation; heating a second section of the formation; and recirculating a portion of the produced mixture from the first section into the second section of the foimation to provide a reducing environment within the second section of the formation.
1753. The method of claim 1752, further comprising maintaining a temperature within the first section or the second section within a pyrolysis temperature range.
1754. The method of claim 1752, wherein heating the first or the second section comprises heating with an electrical heater.
1755. The method of claim 1752, wherein heating the first or the second section comprises heating with a surface burner.
1756. The method of claim 1752, wherein heating the first or the second section comprises heating with a flameless distributed combustor.
1757. The method of claim 1752, wherein heating the first or the second section comprises heating with a natural disfributed combustor.
1758.' The method of claim 1752, further comprising controlling a pressure and a temperature within at least a majority of the first or second section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
1759. The method of claim 1752, further comprising controlling the heat such that an average heating rate of the first or the second section is less than about 1 °C per day during pyrolysis.
1760. The method of claim 1752, wherein heating the first or the second section comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from one or more heat sources, wherein the foπnation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and
wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the foπnation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1761. The method of claim 1752, wherein heating the first or the second section comprises fransfening heat substantially by conduction.
1762. The method of claim 1752, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1763. The method of claim 1752, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1764. The method of claim 1752, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1765. The method of claim 1752, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1766. The method of claim 1752, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1767. The method of claim 1752, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1768. The method of claim 1752, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1769. The method of claim 1752, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1770. The method of claim 1752, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1771. The method of claim 1752, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1772. The method of claim 1752, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1773. The method of claim 1752, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1774. The method of claim 1752, wherein the produced mixture comprises ammonia, and wherehi the ammonia is used to produce fertilizer.
1775. The method of claim 1752, further comprising confrolling a pressure within at least a majority of the first or second section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1776. The method of claim 1752, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1777. The method of claim 1776, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1778. The method of claim 1752, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the foπnation having carbon numbers greater than about 25.
1779. The method of claim 1752, further comprising: providing hydrogen (H2) to the first or second section to hydrogenate hydrocarbons within the ffrst or second section; and heating a portion of the first or second section with heat from hydrogenation.
1780. The method of claim 1752, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1781. The method of claim 1752, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1782. The method of claim 1781, wherein at least about 20 heat sources are disposed in the fonnation for each production well.
1783. The method of claim 1752, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1784. The method of claim 1752, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1785. A method of freating a relatively low penneability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the foπnation; and allowing the heat to fransfer from the one or more heat sources to a selected section of the formation such that a permeability of a majority of at least a portion of the selected section increases substantially uniformly.
1786. The method of claim 1785, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foimation.
1787. The method of claim 1785, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1788. The method of claim 1785, wherein the one or more heat sources comprise electrical heaters.
1789. The method of claim 1785, wherein the one or more heat sources comprise surface burners.
1790. The method of claim 1785, wherein the one or more heat sources comprise flameless disfributed combustors.
1791. The method of claim 1785, wherein the one or more heat sources comprise natural distributed combustors.
1792. The method of claim 1785, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a fimction of pressure.
1793. The method of claim 1785, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1794. The method of claim 1785, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volmne (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherehi heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1795. The method of claim 1785, wherein allowing the heat to ttansfer comprises fransfening heat substantially by conduction.
1796. The method of claim 1785, wherein providing heat from the one or more heat sources comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °C).
1797. The method of claim 1785, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1798. The method of claim 1785, further comprismg producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1799. The method of clahn 1785, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1800. The method of claim 1785, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1801. The method of claim 1785, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1802. The method of claim 1785, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1803. The method of claim 1785, further comprising producing a mixture from the foimation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1804. The method of claim 1785, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1805. The method of claim 1785, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1806. The method of claim 1785, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1807. The method of claim 1785, further comprising producing a mixture from the foimation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1808. The method of claim 1785, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1809. The method of claim 1785, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1810. The method of claim 1785, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1811. The method of claim 1785, further comprising confrolling formation conditions to produce a mixture from the formation, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1812. The method of claim 1785, further comprising producing a mixture from the foπnation, wherein a partial pressure of H2 within the mixture is measured when the mixture is at a production well. '
1813. The method of claim 1785, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1814. The method of claim 1785, further comprising producing a mixture from the formation and controlling foimation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1815. The method of claim 1785, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1816. The method of claim 1785, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1817. The method of claim 1785, wherein allowing the heat to ttansfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
1818. The method of claim 1785, further comprising producing a mixture in a production well, wherein at least about 7 heat sources are disposed in the foπnation for each production well.
1819. The method of claim 1818, wherein at least about 20 heat sources are disposed in the formation for each production well.
1820. The method of claim 1785, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1821. The method of clahn 1785, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1822. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the fonnation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and confrolling the heat to yield at least about 15 % by weight of a total organic carbon content of at least some of the relatively low permeability formation containing heavy hydrocarbons into condensable hydrocarbons.
1823. The method of claim 1822, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1824. The method of claim 1822, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1825. The method of claim 1822, wherein the one or more heat sources comprise electrical heaters.
1826. The method of claim 1822, wherein the one or more heat sources comprise surface burners.
1827. The method of claim 1822, wherein the one or more heat sources comprise flameless disfributed combustors.
1828. The method of clahn 1822, wherein the one pr more heat sources comprise natural distributed combustors.
1829. The method of claim 1822, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
1830. The method of claim 1822, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1831. The method of claim 1822, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heatmg pyrolyzes at least some hydrocarbons within the selected volume of the fonnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1832. The method of claim 1822, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
1833. The method of claim 1822, wherein providing heat from the one or more heat sources comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °C).
1834. The method of claim 1822, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1835. The method of claim 1822, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1836. The method of claim 1822, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1837. The method of claim 1822, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1838. The method of claim 1822, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1839. The method of claim 1822, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1840. The method of claim 1822, further comprising producing a mixture from the foimation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1841. The method of claim 1822, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1842. The method of claim 1822, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1843. The method of claim 1822, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1844. The method of claim 1822, further comprising producing a mixture from the fonnation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1845. The method of claim 1822, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1846. The method of claim 1822, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherehi the ammonia is used to produce fertilizer.
1847. The method of claim 1822, further comprising confrolling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1848. The method of claim 1822, further comprising confrolling formation conditions to produce a mixture from the formation, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1849. The method of claim 1822, further comprising producing a mixture from the formation, wherein a partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1850. The method of claim 1822, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1851. The method of claim 1822, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1852. The method of claim 1822, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1853. The method of claim 1822, further comprismg: producing hydrogen and condensable hydrocarbons from the foπnation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1854. The method of claim 1822, wherein allowing the heat to fransfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.
1855. The method of clahn 1822, wherein allowing the heat to fransfer comprises substantially uniformly increasing a permeability of a majority of the selected section.
1856. The method of claim 1822, further comprismg producing a mixture in a production well, and wherein at least about 7 heat sources are disposed in the foπnation for each production well.
1857. The method of claim 1856, wherein at least about 20 heat sources are disposed in the formation for each production well.
1858. The method of claim 1822, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1859. The method of claim 1822, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1860. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and confrolling the heat to yield greater than about 60 % by weight of hydrocarbons.
1861. The method of claim 1860, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
1862. The method of claim 1860, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1863. The method of claim 1860, wherein the one or more heat sources comprise electrical heaters.
1864. The method of claim 1860, wherein the one or more heat sources comprise surface burners.
1865. The method of claim 1860, wherein the one or more heat sources comprise flameless distributed combustors.
1866. The method of claim 1860, wherein the one or more heat sources comprise natural disfributed combustors.
1867. The method of claim 1860, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
1868. The method of clahn 1860, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1869. The method of claim 1860, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (F) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherem heating energy/day provided to the volmne is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the foπnation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1870. The method of claim 1860, wherein allowing the heat to transfer comprises fransfening heat substantially by conduction.
1871. The method of claim 1860, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1872. The method of claim 1860, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1873. The method of claim 1860, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1874. The method of claim 1860, further comprismg producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1875. The method of claim 1860, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1876. The method of claim 1860, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1877. The method of claim 1860, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1878. The method of claim 1860, further comprising producing a mixture from the foimation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1879. The method of claim 1860, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1880. The method of claim 1860, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1881. The method of claim 1860, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1882. The method of claim 1860, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1883. The method of claim 1860, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1884. The method of claim 1860, further comprising controlling a pressure within at least a majority of the selected section of the foπnation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1885. The method of claim 1860, further comprising confrolling fonnation conditions to produce a mixture from the formation, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1886. The method of claim 1860, further comprising producing a mixture from the formation, wherein a partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1887. The method of claim 1860, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1888. The method of claim 1860, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
1889. The method of claim 1860, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1890. The method of claim 1860, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1891. The method of claim 1860, further comprising producing a mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1892. The method of claim 1891 , wherein at least about 20 heat sources are disposed in the formation for each production well.
1893. The method of claim 1860, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
1894. The method of clahn 1860, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the foimation to form a repetitive pattern of units.
1895. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: heating a first section of the formation to pyrolyze at least some hydrocarbons in the first section and produce a first mixture from the formation;
heating a second section of the formation to pyrolyze at least some hydrocarbons in the second section and produce a second mixture from the formation; and leaving an unpyrolyzed section between the first section and the second section to inhibit subsidence of the formation.
1896. The method of claim 1895, further comprising mahitaining a temperature within the first section or the second section within a pyrolysis temperature range.
1897. The method of claim 1895, wherein heating the first section or heating the second section comprises heating with an electrical heater.
1898. The method of claim 1895, wherein heating the first section or heating the second section comprises heating with a surface burner.
1899. The method of claim 1895, wherein heating the first section or heating the second section comprises heating with a flameless disfributed combustor.
1900. The method of claim 1895, wherein heating the first section or heating the second section comprises heating with a natural distributed combustor.
1901. The method of claim 1895, further comprising confrolling a pressure and a temperature within at least a majority of the first or second section of the fonnation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
1902. The method of claim 1895, further comprising controlling the heat such that an average heating rate of the first or second section is less than about 1 °C per day during pyrolysis.
1903. The method of clahn 1895, wherein heating the first section or heating the second section comprises: heating a selected volume (V) of the relatively low peπneability fonnation containing heavy hydrocarbons from one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the foimation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1904. The method of claim 1895, wherein heating the first section or heating the second section comprises fransfening heat substantially by conduction.
1905. The method of claim 1895, wherein the first or second mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1906. The method of claim 1895, wherein the first or second mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1907. The method of claim 1895, wherein the first or second mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1908. The method of claim 1895, wherein the first or second mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
1909. The method of claim 1895, wherein the first or second mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1910. The method of claim 1895, wherein the first or second mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1911. The method of claim 1895, wherein the first or second mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1912. The method of claim 1895, wherein the first or second mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1913. The method of claim 1895, wherein the first or second mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1914. The method of claim 1895, wherein the first or second mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1915. The method of claim 1895, wherein the first or second mixture comprises a non-condensable component, and wherein the non-condensable component comprises hydrogen, and wherein the hydrogen is greater than about 10 % by volume of the non-condensable component and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1916. The method of claim 1895, wherein the ffrst or second mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the first or second mixture is ammonia.
1917. The method of clahn 1895, wherein the first or second mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1918. The method of claim 1895, further comprising controlling a pressure within at least a majority of the first or second section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
1919. The method of claim 1895, further comprising confrolling foπnation conditions to produce the first or second mixture, wherein a partial pressure of H2 within the first or second mixture is greater than about 0.5 bars.
1920. The method of claim 1895, wherein a partial pressure of H2 within the first or second mixture is measured when the first or second mixture is at a production well.
1921. The method of claim 1895, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1922. The method of claim 1895, further comprising confrolling formation conditions by recirculating a portion ofhydrogen from the first or second mixture into the formation.
1923. The method of claim 1895, further comprising: providing hydrogen (H2) to the first or second section to hydrogenate hydrocarbons within the first or second section, respectively; and heating a portion of the first or second section, respectively, with heat from hydrogenation.
1924. The method of claim 1895, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1925. The method of claim 1895, wherein producing the first or second mixture comprises producing the first or second mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1926. The method of claim 1925, wherein at least about 20 heat sources are disposed in the formation for each production well.
1927. The method of claim 1895, further comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1928. The method of claim 1895, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the foπnation to form a repetitive pattern of units.
1929. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and producing a mixture from the formation through one or more production wells, wherein the heating is confrolled such that the mixture can be produced from the formation as a vapor, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1930. The method of claim 1929, wherein at least about 20 heat sources are disposed in the formation for each production well.
1931. The method of claim 1929, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foimation.
1932. The method of claim 1929, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
1933. The method of clahn 1929, wherein the one or more heat sources comprise elecfrical heaters.
1934. The method of claim 1929, wherein the one or more heat sources comprise surface burners.
1935. The method of claim 1929, wherein the one or more heat sources comprise flameless disfributed combustors.
1936. The method of claim 1929, wherein the one or more heat sources comprise natural distributed combustors.
1937. The method of claim 1929, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the foπnation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
1938. The method of claim 1929, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
1939. The method of claim 1929, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherem the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foimation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the foimation, pB is fonnation bulk density, and wherein the heating rate is less than about 10 °C/day.
1940. The method of claim 1929, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.
1941. The method of claim 1929, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1942. The method of clahn 1929, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1943. The method of claim 1929, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about
0.15.
1944. The method of claim 1929, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1945. The method of claim 1929, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1946. The method of clahn 1929, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1947. The method of claim 1929, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1948. The method of claim 1929, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
1949. The method of claim 1929, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1950. The method of claim 1929, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1951. The method of claim 1929, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1952. The method of claim 1929, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1953. The method of claim 1929, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1954. The method of claim 1929, further comprising controlling a pressure within at least a majority of the selected section of the foπnation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1955. The method of claim 1929, further comprising controlling foimation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1956. The method of claim 1955, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
1957. The method of claim 1929, further comprising altering a pressure within the foπnation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1958. The method of claim 1929, further comprising controlling formation conditions by recirculating a portion ofhydrogen from the mixture into the fonnation.
1959. The method of claim 1929, further comprising:
providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1960. The method of claim 1929, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1961. The method of claim 1929, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1962. The method of claim 1929, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a ttiangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1963. A method of treating a relatively low penneability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation, wherein the one or more heat sources are disposed within one or more first wells; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and producing a mixture from the formation through one or more second wells, wherein one or more of the first or second wells are initially used for a first pmpose and are then used for one or more other puφoses.
1964. The method of claim 1963, wherein the first ptupose comprises removing water from the formation, and wherein the second pmpose comprises providing heat to the formation.
1965. The method of claim 1963, wherein the first pmpose comprises removing water from the formation, and wherein the second pmpose comprises producing the mixture.
1966. The method of claim 1963, wherein the first ptupose comprises heating, and wherein the second pmpose comprises removing water from the formation.
1967. The method of clahn 1963, wherein the first puφose comprises producing the mixture, and wherein the second puφose comprises removing water from the formation.
1968. The method of claim 1963, wherein the one or more heat sources comprise elecfrical heaters.
1969. The method of claim 1963, wherein the one or more heat sources comprise surface burners.
1970. The method of claim 1963, wherein the one or more heat sources comprise flameless distributed combustors.
1971. The method of claim 1963, wherein the one or more heat sources comprise natural disfributed combustors.
1972. The method of claim 1963, further comprismg controlling a pressure and a temperature within at least a majority of the selected section of the fonnation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
1973. The method of claim 1963, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1.0 ° C per day during pyrolysis.
1974. The method of claim 1963, wherein providing heat from the one or more heat sources to at least the portion of the formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
1975. The method of claim 1963, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
1976. The method of claim 1963, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
1977. The method of claim 1963, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
1978. The method of claim 1963, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
1979. The method of claim 1963, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
1980. The method of claim 1963, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
1981. The method of claim 1963, wherehi the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
1982. The method of claim 1963, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings. «
1983. The method of claim 1963, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
1984. The method of claim 1963, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
1985. The method of claim 1963, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
1986. The method of claim 1963, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
1987. The method of claim 1963, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
1988. The method of claim 1963, further comprising confrolling a pressure within at least a majority of the selected section of the foπnation, wherein the confrolled pressure is at least about 2.0 bars absolute.
1989. The method of claim 1963, further comprising confrolling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
1990. The method of claim 1989, wherein the partial pressure of H2 is measured when the mixture is at a production well.
1991. The method of claim 1963, further comprising altering a pressure within the foimation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
1992. The method of claim 1963, further comprising controlling formation conditions, wherein confrolling foπnation conditions comprises recirculating a portion ofhydrogen from the mixture into the formation.
1993. The method of claim 1963 , further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
1994. The method of claim 1963, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
1995. The method of claim 1963, wherein producing the mixture comprises producing the mixttire in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
1996. The method of claim 1995, wherein at least about 20 heat sources are disposed in the formation for each production well.
1997. The method of claim 1963, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
1998. The method of claim 1963, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a ttiangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
1999. A method for forming heater wells in a relatively low permeability foπnation containing heavy hydrocarbons, comprising: forming a first wellbore in the formation; forming a second wellbore in the formation using magnetic tracking such that the second wellbore is ananged substantially parallel to the first wellbore; and providing at least one heat source within the first wellbore and at least one heat source within the second wellbore such that the heat sources can provide heat to at least a portion of the formation.
2000. The method of claim 1999, wherein supeφosition of heat from the at least one heat source within the first wellbore and the at least one heat source within the second wellbore pyrolyzes at least some hydrocarbons within a selected section of the formation.
2001. The method of claim 1999, further comprising maintaining a temperature within a selected section within a pyrolysis temperature range.
2002. The method of claim 1999, wherein the heat sources comprise electrical heaters.
2003. The method of claim 1999, wherein the heat sources comprise surface burners.
2004. The method of claim 1999, wherein the heat sources comprise flameless distributed combustors.
2005. The method of claim 1999, wherein the heat sources comprise natural disfributed combustors.
2006. The method of claim 1999, further comprising confrolling a pressure and a temperature within at least a majority of a selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
2007. The method of clahn 1999, further comprising controlling the heat from the heat sources such that heat fransfened from the heat sources to at least the portion of the hydrocarbons is less than about 1 °C per day during pyrolysis.
2008. The method of claim 1999, further comprising: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy /day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is fonnation bulk density, and wherein the heating rate is less than about 10 °C/day.
2009. The method of claim 1999, further comprising allowing the heat to fransfer from the heat sources to at least the portion of the formation substantially by conduction.
2010. The method of clahn 1999, further comprising producing a mixture from the foimation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2011. The method of claim 1999, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
2012. The method of claim 1999, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
2013. The method of claim 1999, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
2014. The method of claim 1999, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
2015. The method of claim 1999, further comprising producing a mixture from the foimation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
2016. The method of claim 1999, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
2017. The method of claim 1999, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
2018. The method of claim 1999, further comprising producing a mixture from the foimation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
2019. The method of claim 1999, further comprising producing a mixture from the formation, wherehi the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
2020. The method of claim 1999, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
2021. The method of claim 1999, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
2022. The method of claim 1999, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
2023. The method of claim 1999, further comprising controlling a pressure within at least a maj ority of a selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
2024. The method of claim 2023, wherein the partial pressure of H2 within the mixture is greater than about 0.5 bars.
2025. The method of claim 1999, further comprising producing a mixture from the formation, wherein a partial pressure of H2 within the mixture is measured when the mixture is at a production well.
2026. The method of claim 1999, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
2027. The method of claim 1999, further comprising producing a mixture from the formation and confrolling foπnation conditions by recirculating a portion ofhydrogen from the mixture mto the formation.
2028. The method of claim 1999, further comprising: providing hydrogen (H2) to the portion to hydrogenate hydrocarbons within the formation; and heating a portion of the formation with heat from hydrogenation.
2029. The method of claim 1999, further comprising: producing hydrogen and condensable hydrocarbons from the foimation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
2030. The method of claim 1999, further comprising producing a mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
2031. The method of claim 2030, wherein at least about 20 heat sources are disposed in the formation for each production well.
2032. The method of clahn 1999, further comprising forming a production well in the foπnation using magnetic tracking such that the production well is substantially parallel to the first wellbore and coupling a wellhead to the thfrd wellbore.
2033. The method of clahn 1999, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
2034. The method of claim 1999, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a ttiangular pattern, and wherein a plurality of the units are repeated over an area of the foimation to form a repetitive pattern of units.
2035. A method for installing a heater well into a relatively low permeability formation containing heavy hydrocarbons, comprising: forming a bore in the ground using a steerable motor and an accelerometer; and providing a heat source within the bore such that the heat source can fransfer heat to at least a portion of the foπnation.
2036. The method of clahn 2035, further comprising installing at least two heater wells, and wherein supeφosition of heat from at least the two heater wells pyrolyzes at least some hydrocarbons within a selected section of the formation.
2037. The method of claim 2035, further comprising maintaining a temperature within a selected section within a pyrolysis temperature range.
2038. The method of claim 2035, wherein the heat source comprises an elecfrical heater.
2039. The method of clahn 2035, wherein the heat source comprises a surface burner.
2040. The method of claim 2035, wherein the heat source comprises a flameless distributed combustor.
2041. The method of clahn 2035, wherein the heat source comprises a natural distributed combustor.
2042. The method of clahn 2035, further comprising confrolling a pressure and a temperature within at least a majority of a selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
2043. The method of claim 2035, further comprising controlling the heat from the heat source such that heat fransfened from the heat source to at least the portion of the formation is less than about 1 °C per day during pyrolysis.
2044. The method of claim 2035, further comprising:
heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the heat source, wherein the formation has an average heat capacity (Cv), and wherehi the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
2045. The method of claim 2035, further comprising allowing the heat to fransfer from the heat source to at least the portion of the formation substantially by conduction.
2046. The method of claim 2035, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2047. The method of claim 2035, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
2048. The method of claim 2035, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
2049. The method of claim 2035, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
2050. The method of claim 2035, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
2051. The method of claim 2035, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
2052. The method of claim 2035, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
2053. The method of claim 2035, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
2054. The method of claim 2035, further comprising producing a mixture from the foimation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
2055. The method of clahn 2035, furtlier comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
2056. The method of claim 2035, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
2057. The method of clahn 2035, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
2058. The method of claim 2035, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
2059. The method of claim 2035, further comprising confrolling a pressure within at least a majority of a selected section of the fonnation, wherein the confrolled pressure is at least about 2.0 bars absolute.
2060. The method of claim 2035, further comprising confrolling formation conditions to produce a mixture from the foimation, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
2061. The method of claim 2060, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
2062. The method of claim 2035, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
2063. The method of claim 2035, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion ofhydrogen from the mixture into the foπnation.
2064. The method of claim 2035, further comprising:
providing hydrogen (H2) to the at least the heated portion to hydrogenate hydrocarbons within the formation; and heating a portion of the formation with heat from hydrogenation.
2065. The method of claim 2035, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
2066. The method of claim 2035, further comprising producing a mixture in a production well, and wherein at least about 7 heat sources are disposed in the fonnation for each production well.
2067. The method of claim 2066, wherein at least about 20 heat sources are disposed in the formation for each production well.
2068. The method of claim 2035, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
2069. The method of claim 2035, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
2070. A method for installing of wells in a relatively low permeability formation containing heavy hydrocarbons, comprising: forming a wellbore in the formation by geosteered drilling; and providing a heat source within the wellbore such that the heat source can fransfer heat to at least a portion of the formation.
2071. The method of claim 2070, further comprising maintaining a temperature within a selected section within a pyrolysis temperature range.
2072. The method of claim 2070, wherein the heat source comprises an elecfrical heater.
2073. The method of clahn 2070, wherein the heat source comprises a surface burner.
2074. The method of claim 2070, wherein the heat source comprises a flameless disfributed combustor.
2075. The method of claim 2070, wherein the heat source comprises a natural distributed combustor.
2076. The method of claim 2070, further comprising controlling a pressure and a temperature within at least a majority of a selected section of the foimation, wherein the pressure is confrolled as a function of temperature, or the temperature is controlled as a function of pressure.
2077. The method of claim 2070, further comprising confrolling the heat from the heat source such that heat fransfened from the heat source to at least the portion of the foπnation is less than about 1 °C per day during pyrolysis.
2078. The method of claim 2070, further comprising: heating a selected volume (V) of the relatively low peπneability formation containing heavy hydrocarbons from the heat source, wherem the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is foimation bulk density, and wherein the heating rate is less than about 10 °C/day.
2079. The method of claim 2070, further comprising allowing the heat to fransfer from the heat source to at least the portion of the formation substantially by conduction.
2080. The method of claim 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2081. The method of claim 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
2082. The method of claim 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
2083. The method of claim 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
2084. The method of claim 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
2085. The method of claim 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
2086. The method of clahn 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
2087. The method of claim 2070, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
2088. The method of claim 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
2089. The method of claim 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
2090. The method of claim 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
2091. The method of claim 2070, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
2092. The method of claim 2070, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
2093. The method of claim 2070, further comprising confrolling a pressure within at least a majority of a selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
2094. The method of claim 2070, further comprising controlling foimation conditions to produce a mixture from the formation, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
2095. The method of claim 2094, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
2096. The method of claim 2070, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the foimation having carbon numbers greater than about 25.
2097. The method of claim 2070, further comprising producing a mixture from the formation and confrolling formation conditions by recirculating a portion ofhydrogen from the mixture into the foπnation.
2098. The method of claim 2070, further comprising: providing hydrogen (H2) to at least the heated portion to hydrogenate hydrocarbons within the foπnation; and heating a portion of the formation with heat from hydrogenation.
2099. The method of claim 2070, further comprising: producing hydrogen and condensable hydrocarbons from the foimation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
2100. The method of claim 2070, further comprising producing a mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
2101. The method of claim 2100, wherein at least about 20 heat sources are disposed in the formation for each production well.
2102. The method of claim 2070, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
2103. The method of claim 2070, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the foimation to form a repetitive pattern of units.
2104. A method of freating a relatively low permeability foimation containing heavy hydrocarbons in situ, comprising: heating a selected section of the formation with a heating element placed within a wellbore, wherein at least one end of the heating element is free to move axially within the wellbore to allow for thermal expansion of the heating element.
2105. The method of claim 2104, further comprising at least two heating elements within at least two wellbores, and wherein supeφosition of heat from at least the two heating elements pyrolyzes at least some hydrocarbons within a selected section of the formation.
2106. The method of claim 2104, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
2107. The method of claim 2104, wherein the heating element comprises a pipe-in-pipe heater.
2108. The method of claim 2104, wherein the heating element comprises a flameless distributed combustor.
2109. The method of claim 2104, wherein the heating element comprises a mineral insulated cable coupled to a support, and wherein the support is free to move within the wellbore.
2110. The method of claim 2104, wherein the heating element comprises a mineral insulated cable suspended from a wellhead.
2111. The method of clahn 2104, further comprising confrolling a pressure and a temperature within at least a majority of a heated section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
2112. The method of claim 2104, further comprising controlling the heat such that an average heating rate of the heated section is less than about 1 °C per day during pyrolysis.
2113. The method of claim 2104, wherein heating the section of the formation further comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the heating element, wherein the fonnation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the foπnation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *p wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
2114. The method of claim 2104, wherein heating the section of the formation comprises fransfening heat substantially by conduction.
2115. The method of clahn 2104, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2116. The method of claim 2104, further comprising producing a mixture from the fonnation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
2117. The method of claim 2104, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
2118. The method of claim 2104, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
2119. The method of claim 2104, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
2120. The method of claim 2104, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
2121. The method of claim 2104, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
2122. The method of claim 2104, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
2123. The method of claim 2104, further comprising producing a mixture from the formation, wherehi the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
2124. The method of claim 2104, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
2125. The method of claim 2104, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
2126. The method of claim 2104, further comprising producing a mixture from the fonnation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
2127. The method of claim 2104, further comprising producing a mixture from the foπnation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
2128. The method of claim 2104, further comprising confrolling a pressure within the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
2129. The method of claim 2104, further comprising confrolling formation conditions to produce a mixture from the formation, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
2130. The method of claim 2129, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
2131. The method of claim 2104, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
2132. The method of claim 2104, further comprising producing a mixture from the formation and confrolling foimation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
2133. The method of claim 2104, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the heated section; and heating a portion of the section with heat from hydrogenation.
2134. The method of claim 2104, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
2135. The method of claim 2104, further comprising producing a mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
2136. The method of claim 2135, wherein at least about 20 heat sources are disposed in the fonnation for each production well.
2137. The method of claim 2104, further comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
2138. The method of claim 2104, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a ttiangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
2139. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the foimation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and producing a mixture from the formation through a production well, wherein the production well is located such that a majority of the mixture produced from the formation comprises non-condensable hydrocarbons and a non-condensable component comprising hydrogen.
2140. The method of claim 2139, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
2141. The method of claim 2139, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
2142. The method of claim 2139, wherein the production well is less than approximately 6 m from a heat source of the one or more heat sources.
2143. The method of claim 2139, wherein the production well is less than approximately 3 m from a heat source of the one or more heat sources.
2144. The method of claim 2139, wherein the production well is less than approxhnately 1.5 m from a heat source of the one or more heat sources.
2145. The method of claim 2139, wherein an additional heat source is positioned within a wellbore of the production well.
2146. The method of claim 2139, wherein the one or more heat sources comprise electrical heaters.
2147. The method of claim 2139, wherein the one or more heat sources comprise surface burners.
2148. The method of claim 2139, wherein the one or more heat sources comprise flameless disfributed combustors.
2149. The method of claim 2139, wherein the one or more heat sources comprise natural distributed combustors.
2150. The method of claim 2139, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
2151. The method of claim 2139, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
2152. The method of claim 2139, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation: Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the foimation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
2153. The method of claim 2139, wherein allowing the heat to fransfer from the one or more heat sources to the selected section comprises fransfening heat substantially by conduction.
2154. The method of claim 2139, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2155. The method of claim 2139, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
2156. The method of claim 2139, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
2157. The method of claim 2139, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
2158. The method of claim 2139, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
2159. The method of claim 2139, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
2160. The method of claim 2139, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
2161. The method of clahn 2139, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
2162. The method of claim 2139, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
2163. The method of clahn 2139, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
2164. The method of claim 2139, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
2165. The method of claim 2139, wherehi the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
2166. The method of claim 2139, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
2167. The method of claim 2139, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
2168. The method of claim 2139, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
2169. The method of claim 2168, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
2170. The method of claim 2139, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
2171. The method of claim 2139, further comprishig confrolling fonnation conditions by recfrculatmg a portion of the hydrogen from the mixture into the formation.
2172. The method of claim 2139, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
2173. The method of claim 2139, further comprising: producing condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
2174. The method of clahn 2139, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
2175. The method of claim 2174, wherein at least about 20 heat sources are disposed in the fonnation for each production well.
2176. The method of claim 2139, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
2177. The method of claim 2139, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
2178. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat to at least a portion of the formation from one or more first heat sources placed within a pattern in the formation; allowing the heat to fransfer from the one or more first heat sources to a first section of the formation; heating a second section of the foπnation with at least one second heat source, wherein the second section is located within the first section, and wherein at least the one second heat source is configured to raise an average temperature of a portion of the second section to a higher temperature than an average temperature of the first section; and
producing a mixture from the foπnation through a production well positioned within the second section, wherein a majority of the produced mixture comprises non-condensable hydrocarbons and a non-condensable component comprising H2 components.
2179. The method of claim 2178, wherehi the one or more ffrst heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the first section of the formation.
2180. The method of claim 2178, further comprising maintaining a temperature within the first section within a pyrolysis temperature range.
2181. The method of claim 2178, wherein at least the one heat source comprises a heater element positioned within the production well.
2182. The method of claim 2178, wherein at least the one second heat source comprises an electrical heater.
2183. The method of claim 2178, wherein at least the one second heat source comprises a surface burner.
2184. The method of claim 2178, wherein at least the one second heat source comprises a flameless disfributed combustor.
2185. The method of claim 2178, wherein at least the one second heat source comprises a natural distributed combustor.
2186. The method of claim 2178, further comprising confrolling a pressure and a temperature within at least a majority of the first or the second section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
2187. The method of clahn 2178, further comprising confrolling the heat such that an average heating rate of the first section is less than about 1 °C per day during pyrolysis.
2188. The method of claim 2178, wherein providing heat to the formation further comprises: heating a selected volume (I7) of the relatively low penneability formation containing heavy hydrocarbons from the one or more first heat sources, wherein the foπnation has an average heat capacity (C„), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volmne is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is foimation bulk density, and wherein the heating rate is less than about 10 °C/day.
2189. The method of claim 2178, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
2190. The method of claim 2178, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2191. The method of claim 2178, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
2192. The method of clahn 2178, wherem a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
2193. The method of claim 2178, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
«
2194. The method of clahn 2178, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
2195. The method of claim 2178, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
2196. The method of claim 2178, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
2197. The method of claim 2178, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
2198. The method of claim 2178, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
2199. The method of claim 2178, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
2200. The method of claim 2178, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by
volume of the non-condensable component, and wherehi the hydrogen is less than about 80 % by volume of the non-condensable component.
2201. The method of claim 2178, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
2202. The method of claim 2178, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
2203. The method of claim 2178, further comprising confrolling a pressure within at least a majority of the first or the second section of the foπnation, wherein the confrolled pressure is at least about 2.0 bars absolute.
2204. The method of claim 2178, further comprising confrolling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
2205. The method of claim 2204, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
2206. The method of claim 2178, further comprising altering a pressure within the fonnation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
2207. The method of claim 2178, further comprising confrolling formation conditions by recirculating a portion ofhydrogen from the mixture into the foπnation.
2208. The method of claim 2178, further comprising: providing hydrogen (H2) to the first or second section to hydrogenate hydrocarbons within the first or second section, respectively; and heating a portion of the ffrst or second section, respectively, with heat from hydrogenation.
2209. The method of claim 2178, further comprising: producing condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
2210. The method of clahn 2178, wherein at least about 7 heat sources are disposed in the formation for each production well.
2211. The method of claim 2210, wherein at least about 20 heat sources are disposed in the foπnation for each production well.
2212. The method of claim 2178, further comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, and wherein the unit of heat sources comprises a ttiangular pattern.
2213. The method of claim 2178, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
2214. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat into the foπnation from a plurality of heat sources placed in a pattern within the formation, wherein a spacing between heat sources is greater than about 6 m; allowing the heat to transfer from the plurality of heat sources to a selected section of the formation; producing a mixture from the formation from a plurality of production wells, wherein the plurality of production wells are positioned within the pattern, and wherein a spacing between production wells is greater than about 12 m.
2215. The method of claim 2214, wherein supeφosition of heat from the plurality of heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
2216. The method of claim 2214, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.
2217. The method of claim 2214, wherein the plurality of heat sources comprises elecfrical heaters.
2218. The method of claim 2214, wherein the plurality of heat sources comprises surface burners.
2219. The method of claim 2214, wherein the plurality of heat sources comprises flameless disfributed combustors.
2220. The method of claim 2214, wherein the plurality of heat sources comprises natural disfributed combustors.
2221. The method of claim 2214, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is confrolled as a function of temperature, or the temperature is confrolled as a function of pressure.
2222. The method of claim 2214, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
2223. The method of claim 2214, wherein providing heat from the plurality of heat sources comprises: heating a selected volume (V) of the relatively low permeability foπnation containing heavy hydrocarbons from the plurality of heat sources, wherein the fonnation has an ayerage heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is foimation bulk density, and wherein the heating rate is less than about 10 °C/day.
2224. The method of claim 2214, wherein allowing the heat to fransfer comprises fransfening heat substantially by conduction.
2225. The method of claim 2214, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
2226. The method of claim 2214, wherein the produced mixture comprises condensable hydrocarbons, and wherehi about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
2227. The method of claim 2214, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
2228. The method of claim 2214, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
2229. The method of claim 2214, wherein the produced mixttire comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
2230. The method of claim 2214, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
2231. The method of claim 2214, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
2232. The method of claim 2214, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
2233. The method of claim 2214, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
2234. The method of claim 2214, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
2235. The method of claim 2214, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
2236. The method of claim 2214, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
2237. The method of claim 2214, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
2238. The method of claim 2214, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the confrolled pressure is at least about 2.0 bars absolute.
2239. The method of claim 2214, further comprising confrolling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars.
2240. The method of claim 2239, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well.
2241. The method of clahn 2214, further comprising altering a pressure within the foimation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
2242. The method of claim 2214, further comprismg confrolling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.
2243. The method of claim 2214, further comprising: providing hydrogen (H2) to the selected section to hydrogenate hydrocarbons within the selected section; and heating a portion of the selected section with heat from hydrogenation.
2244. The method of claim 2214, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
2245. The method of clahn 2214, wherein at least about 7 heat sources are disposed in the formation for each production well.
2246. The method of claim 2245, wherein at least about 20 heat sources are disposed in the formation for each production well.
2247. The method of claim 2214, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
2248. The method of claim 2214, further comprising providing heat from three or more heat sources to at least a portion of the foimation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
2249. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: a heater disposed in an opening in the formation, wherein the heater is configured to provide heat to at least a portion of the foimation during use; an oxidizing fluid source; a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2250. The system of claim 2249, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2251. The system of claim 2249, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.
2252. The system of claim 2249, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to confrol a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.
2253. The system of claim 2249, wherein the conduit is further configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2254. The system of claim 2249, wherein the conduit is further configured to remove an oxidation product.
2255. The system of claim 2249, wherein the conduit is further configured to remove an oxidation product such that the oxidation product transfers substantial heat to the oxidizing fluid.
2256. The system of claim 2249, wherein the conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2257. The system of claim 2249, wherein the conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.
2258. The system of claim 2249, wherein the conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2259. The system of claim 2249, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2260. The system of claim 2249, further comprising a center conduit disposed within the conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configured to remove an oxidation product during use.
2261. The system of clahn 2249, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m. ■
2262. The system of claim 2249, further comprising a conductor disposed in a second conduit, wherein the second conduit is disposed within the opening, and wherein the conductor is configured to heat at least a portion of the formation during application of an electrical cunent to the conductor.
2263. The system of clahn 2249, further comprising an insulated conductor disposed within the opening, wherein the insulated conductor is configured to heat at least a portion of the formation during application of an elecfrical cunent to the insulated conductor.
2264. The system of claim 2249, further comprising at least one elongated member disposed within the opening, wherein the at least the one elongated member is configured to heat at least a portion of the formation during application of an electrical cunent to the at least the one elongated member.
2265. The system of claim 2249, further comprising a heat exchanger disposed external to the formation, wherein the heat exchanger is configured to heat the oxidizing fluid, wherein the conduit is further configured to provide the heated oxidizing fluid into the openmg during use, and wherein the heated oxidizing fluid is configured to heat at least a portion of the formation during use.
2266. The system of claim 2249, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2267. The system of claim 2249, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing comprises steel.
2268. The system of claim 2249, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2269. The system of claim 2249, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2270. The system of claim 2249, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2271. The system of claim 2249, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2272. The system of claim 2249, wherein the system is further configured such that fransfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2273. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: a heater configurable to be disposed in an opening in the formation, wherein the heater is further configurable to provide heat to at least a portion of the formation during use; a conduit configurable to be disposed in the opening, wherein the conduit is configurable to provide an oxidizing fluid from an oxidizing fluid source to a reaction zone in the formation during use, and wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is further configurable to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2274. The system of claim 2273, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2275. The system of claim 2273, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.
2276. The system of clahn 2273, wherehi the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.
2277. The system of claim 2273, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2278. The system of claim 2273, wherein the conduit is further configurable to remove an oxidation product.
2279. The system of claim 2273, wherein the conduit is further configurable to remove an oxidation product, such that the oxidation product fransfers heat to the oxidizing fluid.
2280. The system of claim 2273, wherein the conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approxhnately equal to a flow rate of the oxidation product in the conduit.
2281. The system of claim 2273, wherein the conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are confrolled to reduce contamination of the oxidation product by the oxidizing fluid.
2282. The system of claim 2273, wherein the conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the fonnation beyond the reaction zone.
2283. The system of claim 2273, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2284. The system of claim 2273, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configurable to remove an oxidation product during use.
2285. The system of claim 2273, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2286. The system of claim 2273, further comprising a conductor disposed in a second conduit, wherein the second conduit is disposed within the opening, and wherein the conductor is configurable to heat at least a portion of the foπnation during application of an elecfrical cunent to the conductor.
2287. The system of claim 2273, further comprising an insulated conductor disposed within the opening, wherein the insulated conductor is configurable to heat at least a portion of the fonnation during application of an electrical cunent to the insulated conductor.
2288. The system of claim 2273, further comprising at least one elongated member disposed withhi the opening, wherein the at least the one elongated member is configurable to heat at least a portion of the formation during application of an elecfrical cunent to the at least the one elongated member.
2289. The system of claim 2273, further comprising a heat exchanger disposed external to the formation, wherein the heat exchanger is configurable to heat the oxidizing fluid, wherein the conduit is further configurable to provide the heated oxidizing fluid into the opening during use, and wherein the heated oxidizing fluid is configurable to heat at least a portion of the formation during use.
2290. The system of claim 2273, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2291. The system of claim 2273, further comprising an overburden casing coupled to the opening, wherehi the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2292. The system of claim 2273, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2293. The system of clahn 2273, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2294. The system of clahn 2273, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2295. The system of claim 2273, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the fonnation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2296. The system of claim 2273, wherein the system is further configurable such that fransfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2297. The system of claim 2273, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a heater disposed in an opening in the foimation, wherein the heater is configured to provide heat to at least a portion of the foimation during use; r an oxidizing fluid source; a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherehi the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2298. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid; providing the oxidizing fluid to a reaction zone in the formation; allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and fransfening the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the foπnation.
2299. The method of claim 2298, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.
2300. The method of claim 2298, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.
2301. The method of claim 2298, further comprising confrolling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is confrolled.
2302. The method of claim 2298, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.
2303. The method of claim 2298, wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.
2304. The method of claim 2298, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.
2305. The method of claim 2298, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the foπnation through the conduit and fransfening heat from the oxidation product in the conduit to oxidizing fluid in the conduit.
2306. The method of claim 2298, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the foπnation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2307. The method of claim 2298, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the foπnation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.
2308. The method of claim 2298, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.
2309. The method of claim 2298, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.
2310. The method of claim 2298, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.
2311. The method of claim 2298, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2312. The method of claim 2298, wherein heating the portion comprises applying elecfrical cunent to a conductor disposed in a conduit, wherein the conduit is disposed within the opening.
2313. The method of claim 2298, wherein heating the portion comprises applying elecfrical cunent to an insulated conductor disposed within the opening.
2314. The method of claim 2298, wherein heating the portion comprises applying elecfrical cunent to at least one elongated member disposed within the opening.
2315. The method of claim 2298, wherein heating the portion comprises heatmg the oxidizing fluid in a heat exchanger disposed external to the fonnation such that providing the oxidizing fluid into the opening comprises fransfening heat from the heated oxidizing fluid to the portion.
2316. The method of claim 2298, further comprising removing water from the formation prior to heating the portion.
2317. The method of claim 2298, further comprising confrollmg the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.
2318. The method of claim 2298, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2319. The method of claim 2298, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2320. The method of claim 2298, further comprising coupling an overburden casing to the opening, wherehi the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2321. The method of claim 2298, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2322. The method of clahn 2298, wherein the pyrolysis zone is substantially adjacent to the reaction zone.
2323. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprising:
a heater disposed in an opening in the formation, wherein the heater is configured to provide heat to at least a portion of the formation during use; an oxidizing fluid source; a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizmg fluid from the oxidizing fluid source to a reaction zone in the formation during use, wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone, and wherein the conduit is further configured to remove an oxidation product from the formation during use; and wherein the system is configured to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2324. The system of claim 2323, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2325. The system of claim 2323, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.
2326. The system of claim 2323, wherehi the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to confrol a flow of the oxidizing fluid such that a rate of oxidation in the formation is confrolled.
2327. The system of claim 2323, wherein the conduit is further configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2328. The system of claim 2323, wherein the conduit is further configured such that the oxidation product fransfers heat to the oxidizing fluid.
2329. The system of clahn 2323, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2330. The system of claim 2323, wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.
2331. The system of claim 2323, wherehi the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2332. The system of claim 2323, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2333. The system of clahn 2323, further comprising a center conduit disposed within the conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use.
2334. The system of claim 2323, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2335. The system of claim 2323, further comprising a conductor disposed in a second conduit, wherein the second conduit is disposed within the opening, and wherein the conductor is configured to heat at least a portion of the foimation during application of an elecfrical cunent to the conductor.
2336. The system of claim 2323, further comprising an insulated conductor disposed within the opening, wherein the insulated conductor is configured to heat at least a portion of the formation during application of an elecfrical cunent to the insulated conductor.
2337. The system of claim 2323, further comprising at least one elongated member disposed within the opening, wherein the at least the one elongated member is configured to heat at least a portion of the formation during application of an elecfrical cunent to the at least the one elongated member.
2338. The system of claim 2323, further comprising a heat exchanger disposed external to the formation, wherehi the heat exchanger is configured to heat the oxidizing fluid, wherein the conduit is further configured to provide the heated oxidizing fluid into the opening during use, and wherein the heated oxidizing fluid is configured to heat at least a portion of the foimation during use.
2339. The system of claim 2323, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2340. The system of claim 2323, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2341. The system of claim 2323, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2342. The system of claim 2323, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2343. The system of claim 2323, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherem a packing material is disposed at a
junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2344. The system of claim 2323, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2345. The system of claim 2323, wherein the system is further configured such that fransfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2346. A system configurable to heat a relatively low penneability formation containing heavy hydrocarbons, comprising: a heater configurable to be disposed in an opening in the fonnation, wherein the heater is further configurable to provide heat to at least a portion of the formation during use; a conduit configurable to be disposed in the opening, wherein the conduit is further configurable to provide an oxidizing fluid from an oxidizing fluid source to a reaction zone in the foπnation during use, wherehi the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone, and wherein the conduit is further configurable to remove an oxidation product from the formation during use; and wherein the system is further configurable to allow heat to ttansfer substantially by conduction from the reaction zone to a pyrolysis zone during use.
2347. The system of claim 2346, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2348. The system of claim 2346, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.
2349. The system of claim 2346, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to confrol a flow of the oxidizing fluid such that a rate of oxidation in the formation is confrolled.
2350. The system of claim 2346, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2351. The system of claim 2346, wherein the conduit is further configurable such that the oxidation product transfers heat to the oxidizing fluid.
2352. The system of claim 2346, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2353. The system of claim 2346, wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are confrolled to reduce contamination of the oxidation product by the oxidizing fluid.
2354. The system of claim 2346, wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2355. The system of claim 2346, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2356. The system of claim 2346, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use.
2357. The system of claim 2346, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2358. The system of claim 2346, further comprising a conductor disposed in a second conduit, wherein the second conduit is disposed within the opening, and wherein the conductor is configurable to heat at least a portion of the foπnation during application of an electrical cunent to the conductor.
2359. The system of claim 2346, further comprising an insulated conductor disposed within the opening, wherein the insulated conductor is configurable to heat at least a portion of the formation during application of an electrical cunent to the insulated conductor.
2360. The system of claim 2346, further comprising at least one elongated member disposed within the opening, wherein the at least the one elongated member is configurable to heat at least a portion of the foπnation during application of an electrical cunent to the at least the one elongated member.
2361. The system of clahn 2346, further comprising a heat exchanger disposed external to the formation, wherein the heat exchanger is configurable to heat the oxidizing fluid, wherein the conduit is further configurable to provide the heated oxidizing fluid into the opening during use, and wherein the heated oxidizing fluid is configurable to heat at least a portion of the formation during use.
2362. The system of claim 2346, further comprismg an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2363. The system of claim 2346, further comprising an overburden casing coupled to the openmg, wherein the overburden casing is disposed in an overburden of the fonnation, and wherein the overburden casing comprises steel.
2364. The system of claim 2346, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2365. The system of claim 2346, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2366. The system of claim 2346, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2367. The system of claim 2346, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2368. The system of claim 2346, wherein the system is further configurable such that fransfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2369. The system of claim 2346, wherein the system is configured to heat a relatively low permeability foimation containing heavy hydrocarbons, and wherein the system comprises: a heater disposed in an opening in the formation, wherein the heater is configured to provide heat to at least a portion of the formation during use; an oxidizing fluid source; a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the foπnation during use, wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone, and wherein the conduit is further configured to remove an oxidation product from the foimation during use; and wherein the system is configured to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2370. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid, wherein the portion is located substantially adjacent to an opening in the formation; providing the oxidizing fluid to a reaction zone in the formation; allowing the oxidizing gas to react with at least a portion of the hydrocarbons at the reaction zone to generate heat in the reaction zone;
removing at least a portion of an oxidation product through the opening; and fransfening the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the foπnation.
2371. The method of claim 2370, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.
2372. The method of claim 2370, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.
2373. The method of claim 2370, further comprising controlling a flow of the oxidizhig fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is confrolled.
2374. The method of claim 2370, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially maintained within the reaction zone.
2375. The method of claim 2370, wherein a conduit is disposed in the opening, the method furtlier comprising cooling the conduit with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2376. The method of claim 2370, wherein a conduit is disposed within the opening, and wherein removing at least the portion of the oxidation product through the opening comprises removing at least the portion of the oxidation product tiirough the conduit.
2377. The method of claim 2370, wherein a conduit is disposed within the opening, and wherein removing at least the portion of the oxidation product through the opening comprises removing at least the portion of the oxidation product through the conduit, the method further comprising ttansfening substantial heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.
2378. The method of claim 2370, wherein a conduit is disposed within the opening, wherein removing at least the portion of the oxidation product through the opening comprises removing at least the portion of the oxidation product through the conduit, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2379. The method of claim 2370, wherein a conduit is disposed within the opening, and wherein removing at least the portion of the oxidation product through the opening comprises removing at least the portion of the oxidation product through the conduit, the method further comprising confrolling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.
2380. The method of claim 2370, wherehi a conduit is disposed within the opening, and wherein removing at least the portion of the oxidation product through the opening comprises removing at least the portion of the oxidation product through the conduit, the method further comprising substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.
2381. The method of claim 2370, further comprishig substantially inhibiting the oxidizing fluid from flowing into portions of the foπnation beyond the reaction zone.
2382. The method of claim 2370, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizmg fluid into the opening through the center conduit and removing at least a portion of the oxidation product through the outer conduit.
2383. The method of claim 2370, wherein the portion of the formation extends radially from the openhig a width of less than approximately 0.2 m.
2384. The method of claim 2370, wherein heating the portion comprises applying elecfrical cunent to a conductor disposed in a conduit, wherein the conduit is disposed within the opening.
2385. The method of clahn 2370, wherein heating the portion comprises applying elecfrical cunent to an insulated conductor disposed within the opening.
2386. The method of claim 2370, wherein heating the portion comprises applying electrical cunent to at least one elongated member disposed within the opening.
2387. The method of claim 2370, wherein heating the portion comprises heating the oxidizing fluid in a heat exchanger disposed external to the formation such that providing the oxidizing fluid into the opening comprises fransfening heat from the heated oxidizing fluid to the portion.
2388. The method of claim 2370, further comprising removing water from the formation prior to heating the portion.
2389. The method of claim 2370, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nifrogen during oxidation.
2390. The method of claim 2370, further comprising coupling an overburden casing to the openhig, wherein the overburden casing is disposed in an overburden of the formation.
2391. The method of clahn 2370, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2392. The method of claim 2370, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2393. The method of claim 2370, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2394. The method of claim 2370, wherein the pyrolysis zone is substantially adjacent to the reaction.
2395. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: an electric heater disposed in an opening in the fonnation, wherein the elecfric heater is configured to provide heat to at least a portion of the formation during use; an oxidizing fluid source; a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2396. The system of claim 2395, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2397. The system of claim 2395, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.
2398. The system of clahn 2395, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is confrolled.
2399. The system of claim 2395, wherein the conduit is further configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2400. The system of claim 2395, wherein the conduit is further configured to remove an oxidation product.
2401. The system of claim 2395, wherein the conduit is further configured to remove an oxidation product, such that the oxidation product fransfers heat to the oxidizing fluid.
2402. The system of claim 2395, wherein the conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approxunately equal to a flow rate of the oxidation product in the conduit.
2403. The system of claim 2395, wherein the conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are confrolled to reduce contamination of the oxidation product by the oxidizing fluid.
2404. The system of claim 2395, wherein the conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the foπnation beyond the reaction zone.
2405. The system of claim 2395, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the foπnation beyond the reaction zone.
2406. The system of claim 2395, further comprising a center conduit disposed within the conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configured to remove an oxidation product during use.
2407. The system of claim 2395, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2408. The system of claim 2395, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2409. The system of claim 2395, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2410. The system of clahn 2395, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2411. The system of claim 2395, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2412. The system of claim 2395, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2413. The system of claim 2395, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2414. The system of claim 2395, wherein the system is further configured such that fransfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2415. A system configurable to heat a relatively low peπneability fonnation containing heavy hydrocarbons, comprising: an elecfric heater configurable to be disposed in an opening in the formation, wherein the elecfric heater is further configurable to provide heat to at least a portion of the formation during use, and wherein at least the portion is located substantially adjacent to the opening; a conduit configurable to be disposed in the opening, wherein the conduit is further configurable to provide an oxidizing fluid from an oxidizing fluid source to a reaction zone hi the formation during use, and wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is further configurable to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2416. The system of claim 2415, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2417. The system of claim 2415, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.
2418. The system of claim 2415, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to confrol a flow of the oxidizing fluid such that a rate of oxidation in the formation is confrolled.
2419. The system of claim 2415, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2420. The system of claim 2415, wherein the conduit is further configurable to remove an oxidation product.
2421. The system of claim 2415, wherein the conduit is further configurable to remove an oxidation product such that the oxidation product fransfers heat to the oxidizing fluid.
2422. The system of clahn 2415, wherein the conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2423. The system of claim 2415, wherein the conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are confrolled to reduce contamination of the oxidation product by the oxidizing fluid.
2424. The system of claim 2415, wherein the conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the foπnation beyond the reaction zone.
2425. The system of claim 2415, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2426. The system of claim 2415, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configurable to remove an oxidation product during use.
2427. The system of claim 2415, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2428. The system of claim 2415, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2429. The system of claim 2415, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2430. The system of claim 2415, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed hi an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2431. The system of claim 2415, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2432. The system of claim 2415, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packhig material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2433. The system of claim 2415 , further comprishig an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2434. The system of claim 2415, wherein the system is further configurable such that fransfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2435. The system of claim 2415, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: an electric heater disposed in an opening in the foπnation, wherein the electric heater is configured to provide heat to at least a portion of the foimation during use; an oxidizing fluid source; a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the foimation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2436. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: a conductor disposed in a first conduit, wherein the first conduit is disposed in an opening in the formation, and wherein the conductor is configured to provide heat to at least a portion of the formation during use; an oxidizing fluid source; a second conduit disposed in the opening, wherein the second conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2437. The system of claim 2436, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2438. The system of claim 2436, wherein the second conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.
2439. The system of claim 2436, wherein the second conduit comprises critical flow orifices, and wherehi the critical flow orifices are configured to confrol a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.
2440. The system of claim 2436, wherein the second conduit is further configured to be cooled with the oxidizing fluid to reduce heating of the second conduit by oxidation.
2441. The system of claim 2436, wherein the second conduit is further configured to remove an oxidation product.
2442. The system of claim 2436, wherein the second conduit is further configured to remove an oxidation product such that the oxidation product fransfers heat to the oxidizing fluid.
2443. The system of claim 2436, wherein the second conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the second conduit.
2444. The system of clahn 2436, wherein the second conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the second conduit and a pressure of the oxidation product in the second conduit are confrolled to reduce contamination of the oxidation product by the oxidizing fluid.
2445. The system of claim 2436, wherehi the second conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the foπnation beyond the reaction zone.
2446. The system of claim 2436, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2447. The system of claim 2436, further comprising a center conduit disposed within the second conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the second conduit is further configured to remove an oxidation product during use.
2448. The system of claim 2436, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2449. The system of claim 2436, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2450. The system of claim 2436, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2451. The system of claim 2436, further comprishig an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2452. The system of claim 2436, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2453. The system of claim 2436, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the fonnation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2454. The system of claim 2436, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2455. The system of claim 2436, wherein the system is further configured such that transfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2456. A system configurable to heat a relatively low peπneability fonnation containing heavy hydrocarbons, comprising: a conductor configurable to be disposed in a first conduit, wherein the first conduit is configurable to be disposed in an opening in the formation, and wherein the conductor is further configurable to provide heat to at least a portion of the foπnation during use; a second conduit configurable to be disposed in the opening, wherein the second conduit is further configurable to provide an oxidizing fluid from an oxidizing fluid source to a reaction zone in the foπnation during use, and wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is further configurable to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2457. The system of claim 2456, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2458. The system of claim 2456, wherein the second conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.
2459. The system of claim 2456, wherein the second conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.
2460. The system of claim 2456, wherein the second conduit is further configurable to be cooled with the oxidizing fluid to reduce heating of the second conduit by oxidation.
2461. The system of claim 2456, wherein the second conduit is further configurable to remove an oxidation product.
2462. The system of claim 2456, wherein the second conduit is further configurable to remove an oxidation product such that the oxidation product transfers heat to the oxidizing fluid.
2463. The system of clahn 2456, wherein the second conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the second conduit.
2464. The system of claim 2456, wherein the second conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the second conduit and a pressure of the oxidation product in the second conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.
2465. The system of claim 2456, wherein the second conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2466. The system of claim 2456, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2467. The system of claim 2456, further comprismg a center conduit disposed within the second conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the second conduit is further configurable to remove an oxidation product during use.
2468. The system of claim 2456, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2469. The system of claim 2456, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2470. The system of claim 2456, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2471. The system of claim 2456, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed hi an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2472. The system of claim 2456, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2473. The system of claim 2456, furtlier comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the fonnation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2474. The system of claim 2456, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2475. The system of claim 2456, wherein the system is further configurable such that fransfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2476. The system of claim 2456, wherein the system is configured to heat a relatively low peπneability formation containing heavy hydrocarbons, and wherein the system comprises: a conductor disposed in a ffrst conduit, wherein the first conduit is disposed in an opening in the foimation, and wherein the conductor is configured to provide heat to at least a portion of the formation during use; an oxidizing fluid source; a second conduit disposed in the opening, wherein the second conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the foimation during use.
2477. An in situ method for heating a relatively low permeability fonnation containing heavy hydrocarbons, comprising: heating a portion of the foπnation to a temperature sufficient to support reaction of hydrocarbons within the portion of the fonnation with an oxidizing fluid, wherein heating comprises applying an elecfrical cunent to a
conductor disposed in a first conduit to provide heat to the portion, and wherein the first conduit is disposed within the opening; providing the oxidizing fluid to a reaction zone in the foπnation; allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and fransfening the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.
2478. The method of claim 2477, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.
2479. The method of claim 2477, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a second conduit disposed in the opening.
2480. The method of claim 2477, furtlier comprishig controlling a flow of the oxidizing fluid with critical flow orifices of a second conduit disposed in the opening such that a rate of oxidation is controlled.
2481. The method of claim 2477, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over thne within the reaction zone.
2482. The method of claim 2477, wherein a second conduit is disposed in the opening, the method further comprising cooling the second conduit with the oxidizing fluid to reduce heating of the second conduit by oxidation.
2483. The method of claim 2477, wherein a second conduit is disposed within the opening, the method further comprising removing an oxidation product from the fonnation through the second conduit.
2484. The method of claim 2477, wherein a second conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation tiirough the second conduit and fransfening heat from the oxidation product in the conduit to the oxidizing fluid in the second conduit.
2485. The method of claim 2477, wherein a second conduit is disposed within the opening, the method further comprishig removing an oxidation product from the foimation through the second conduit, wherein a flow rate of the oxidizhig fluid in the second conduit is approximately equal to a flow rate of the oxidation product in the second conduit.
2486. The method of claim 2477, wherein a second conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the second conduit and confrolling a
pressure between the oxidizing fluid and the oxidation product in the second conduit to reduce contamination of the oxidation product by the oxidizing fluid.
2487. The method of claim 2477, wherein a second conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.
2488. The method of claim 2477, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.
2489. The method of claim 2477, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.
2490. The method of claim 2477, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2491. The method of claim 2477, further comprising removing water from the formation prior to heating the portion.
2492. The method of claim 2477, further comprising confrolling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.
2493. The method of claim 2477, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foπnation.
2494. The method of claim 2477, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2495. The method of claim 2477, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2496. The method of claim 2477, further comprising coupling an overburden casing to the opening, wherehi a packing material is disposed at ajunction of the overburden casing and the opening.
2497. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprising:
an insulated conductor disposed in an opening in the formation, wherein the insulated conductor is configured to provide heat to at least a portion of the formation during use; an oxidizhig fluid source; a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2498. The system of claim 2497, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2499. The system of claim 2497, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.
2500. The system of claim 2497, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.
2501. The system of claim 2497, wherein the conduit is configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2502. The system of claim 2497, wherein the conduit is further configured to remove an oxidation product.
2503. The system of claim 2497, wherein the conduit is further configured to remove an oxidation product, and wherein the conduit is further configured such that the oxidation product fransfers substantial heat to the oxidizing fluid.
2504. The system of claim 2497, wherein the conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2505. The system of claim 2497, wherein the conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the second conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.
2506. The system of claim 2497, wherein the conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the foπnation beyond the reaction zone.
2507. The system of claim 2497, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2508. The system of claim 2497, further comprising a center conduit disposed within the conduit, wherehi the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configured to remove an oxidation product during use.
2509. The system of claim 2497, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2510. The system of claim 2497, furtlier comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the fonnation.
2511. The system of claim 2497, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2512. The system of claim 2497, further comprising an overburden casing coupled to the opening, wherehi the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing is further disposed in cement.
2513. The system of claim 2497, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2514. The system of claim 2497, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2515. The system of claim 2497, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2516. The system of clahn 2497, wherein the system is further configured such that transfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2517. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising:
an insulated conductor configurable to be disposed in an opening in the foπnation, wherein the insulated conductor is further configurable to provide heat to at least a portion of the foπnation during use; a conduit configurable to be disposed in the opening, wherein the conduit is further configurable to provide an oxidizing fluid from an oxidizing fluid source to a reaction zone in the formation during use, and wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is further configurable to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2518. The system of claim 2517, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2519. The system of claim 2517, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.
2520. The system of claim 2517, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to confrol a flow of the oxidizing fluid such that a rate of oxidation in the formation is confrolled.
2521. The system of claim 2517, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2522. The system of claim 2517, wherein the conduit is further configurable to remove an oxidation product.
2523. The system of claim 2517, wherein the conduit is further configurable to remove an oxidation product, such that the oxidation product transfers heat to the oxidizing fluid.
2524. The system of claim 2517, wherein the conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2525. The system of clahn 2517, wherein the conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are confrolled to reduce contamination of the oxidation product by the oxidizing fluid.
2526. The system of claim 2517, wherein the conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2527. The system of claim 2517, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2528. The system of claim 2517, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configurable to remove an oxidation product during use.
2529. The system of claim 2517, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2530. The system of claim 2517, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation.
2531. The system of claim 2517, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the fonnation, and wherein the overburden casing comprises steel.
2532. The system of claim 2517, further comprismg an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2533. The system of claim 2517, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2534. The system of claim 2517, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherehi the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2535. The system of claim 2517, further comprismg an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2536. The system of claim 2517, wherein the system is further configurable such that fransfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2537. The system of claim 2517, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: an insulated conductor disposed in an opening in the formation, wherein the insulated conductor is configured to provide heat to at least a portion of the formation during use;
an oxidizing fluid source; a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2538. An in situ method for heating a relatively low peπneability formation containing heavy hydrocarbons, comprising: heating a portion of the foimation to a temperature sufficient to support reaction of hydrocarbons within the portion of the foπnation with an oxidizing fluid, wherein heating comprises applying an electrical cunent to an insulated conductor to provide heat to the portion, and wherein the insulated conductor is disposed within the opening; providing the oxidizing fluid to a reaction zone in the foπnation; allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and fransfening the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.
2539. The method of claim 2538, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.
2540. The method of claim 2538, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.
2541. The method of claim 2538, further comprising confrolling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is confrolled.
2542. The method of claim 2538, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.
2543. The method of clahn 2538, wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.
2544. The method of claim 2538, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.
2545. The method of claim 2538, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and fransfening heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.
2546. The method of claim 2538, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2547. The method of claim 2538, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.
2548. The method of claim 2538, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.
2549. The method of claim 2538, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.
2550. The method of claim 2538, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.
2551. The method of claim 2538, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2552. The method of claim 2538, further comprising removing water from the formation prior to heating the portion.
2553. The method of claim 2538, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.
2554. The method of clahn 2538, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2555. The method of clahn 2538, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2556. The method of claim 2538, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2557. The method of claim 2538, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2558. The method of claim 2538, wherein the pyrolysis zone is substantially adjacent to the reaction zone.
2559. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a portion of the foπnation to a temperature sufficient to support reaction of hydrocarbons within the portion of the foπnation with an oxidizing fluid, wherein the portion is located substantially adjacent to an opening in the foπnation, wherein heating comprises applying an electrical cunent to an insulated conductor to provide heat to the portion, wherein the insulated conductor is coupled to a conduit, wherein the conduit comprises critical flow orifices, and wherein the conduit is disposed within the opening; providing the oxidizing fluid to a reaction zone in the formation; allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and fransfening the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.
2560. The method of claim 2559, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.
2561. The method of claim 2559, further comprising confrolling a flow of the oxidizing fluid with the critical flow orifices such that a rate of oxidation is controlled.
2562. The method of claim 2559, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.
2563. The method of claim 2559, further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.
2564. The method of clahn 2559, further comprising removing an oxidation product from the formation through the conduit.
2565. The method of claim 2559, further comprising removing an oxidation product from the formation through the conduit and fransfening heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.
2566. The method of claim 2559, further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2567. The method of claim 2559, further comprising removing an oxidation product from the formation through the conduit and confrolling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.
2568. The method of claim 2559, fuither comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.
2569. The method of claim 2559, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.
2570. The method of clahn 2559, wherein a center conduit is disposed within the conduit, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the conduit.
2571. The method of claim 2559, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2572. The method of claim 2559, further comprising removing water from the formation prior to heating the portion.
2573. The method of claim 2559, further comprising confrolling the temperature of the foimation to substantially inhibit production of oxides of nifrogen during oxidation.
2574. The method of claim 2559, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2575. The method of clahn 2559, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2576. The method of claim 2559, further comprising coupling an overburden casing to the openhig, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2577. The method of clahn 2559, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2578. The method of claim 2559, wherein the pyrolysis zone is substantially adjacent to the reaction zone.
2579. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: at least one elongated member disposed in an opening in the foπnation, wherein at least the one elongated member is configured to provide heat to at least a portion of the formation during use; an oxidizing fluid source; a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2580. The system of claim 2579, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2581. The system ofclaim 2579, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.
2582. The system ofclaim 2579, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the foπnation is controlled.
2583. The system ofclaim 2579, wherein the conduit is further configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2584. The system of claim 2579, wherein the conduit is further configured to remove an oxidation product.
2585. The system ofclaim 2579, wherein the conduit is further configured to remove an oxidation product such that the oxidation product transfers heat to the oxidizhig fluid.
2586. The system ofclaim 2579, wherein the conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2587. The system ofclaim 2579, wherein the conduit is fuither configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are confrolled to reduce contamination of the oxidation product by the oxidizing fluid.
2588. The system ofclaim 2579, wherein the conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2589. The system ofclaim 2579, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2590. The system ofclaim 2579, furtlier comprising a center conduit disposed within the conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configured to remove an oxidation product during use.
2591. The system of claim 2579, wherein the portion of the fonnation extends radially from the opening a width of less than approximately 0.2 m.
2592. The system of clahn 2579, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation.
2593. The system ofclaim 2579, further comprising an overburden casing coupled to die opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2594. The system ofclaim 2579, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2595. The system ofclaim 2579, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2596. The system ofclaim 2579, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2597. The system ofclaim 2579, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packhig material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2598. The system of claim 2579, wherein the system is further configured such that transfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2599. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: at least one elongated member configurable to be disposed in an opening in the formation, wherein at least the one elongated member is further configurable to provide heat to at least a portion of the formation during use; a conduit configurable to be disposed in the opening, wherein the conduit is further configurable to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is further configurable to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2600. The system of claim 2599, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2601. The system ofclaim 2599, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.
2602. The system ofclaim 2599, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to confrol a flow of the oxidizing fluid such that a rate of oxidation in the formation is confrolled.
2603. The system of claim 2599, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2604. The system ofclaim 2599, wherein the conduit is further configurable to remove an oxidation product.
2605. The system of claim 2599, wherein the conduit is further configurable to remove an oxidation product such that the oxidation product fransfers heat to the oxidizing fluid.
2606. The system of claim 2599, wherein the conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approxhnately equal to a flow rate of the oxidation product in the conduit.
2607. The system of claim 2599, wherein the conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are confrolled to reduce contamination of the oxidation product by the oxidizing fluid.
2608. The system ofclaim 2599, wherein the conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2609. The system of claim 2599, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.
2610. The system ofclaim 2599, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configurable to remove an oxidation product during use.
2611. The system ofclaim 2599, wherein the portion of the foπnation extends radially from the opening a width of less than approximately 0.2 m.
2612. The system ofclaim 2599, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the fonnation.
2613. The system of claim 2599, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2614. The system ofclaim 2599, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2615. The system ofclaim 2599, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2616. The system of claim 2599, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2617. The system ofclaim 2599, further comprising an overburden casing coupled to the openhig, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2618. The system ofclaim 2599, wherein the system is further configurable such that transfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
2619. The system of claim 2599, wherein the system is configured to heat a relatively low permeability foimation containing heavy hydrocarbons, and wherein the system comprises: at least one elongated member disposed in an opening in the fonnation, wherein at least the one elongated member is configured to provide heat to at least a portion of the foπnation during use; an oxidizing fluid source; a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the foπnation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2620. An in situ method for heating a relatively low penneability fonnation containing heavy hydrocarbons, comprising: heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the foπnation with an oxidizing fluid, wherein heating comprises applying an elecfrical cunent to at least one elongated member to provide heat to the portion, and wherein at least the one elongated member is disposed within the opening; providing the oxidizing fluid to a reaction zone in the formation; allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and fransfening the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.
2621. The method of claim 2620, further comprising ttansporting the oxidizing fluid through the reaction zone by diffusion.
2622. The method ofclaim 2620, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.
2623. The method ofclaim 2620, further comprising controlling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is confrolled.
2624. The method of clahn 2620, further comprishig increasing a flow of the oxidizing fluid in the opening to accoimnodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.
2625. The method of claim 2620, wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.
2626. The method of claim 2620, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.
2627. The method ofclaim 2620, wherehi a conduit is disposed within the opening, the method further comprising removmg an oxidation product from the formation through the conduit and fransfening heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.
2628. The method of claim 2620, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the foimation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2629. The method of claim 2620, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.
2630. The method of claim 2620, wherein a conduit is disposed within the opening, the method further comprishig removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the foimation beyond the reaction zone.
2631. The method of claim 2620, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.
2632. The method of claim 2620, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.
2633. The method ofclaim 2620, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2634. The method of claim 2620, further comprising removing water from the foπnation prior to heating the portion.
2635. The method o claim 2620, further comprising confrolling the temperature of the foπnation to substantially inhibit production of oxides of nifrogen during oxidation.
2636. The method of claim 2620, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2637. The method of clahn 2620, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2638. The method ofclaim 2620, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2639. The method ofclaim 2620, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2640. The method ofclaim 2620, wherein the pyrolysis zone is substantially adjacent to the reaction zone.
2641. A system configured to heat a relatively low permeability fonnation containing heavy hydrocarbons, comprising: a heat exchanger disposed external to the formation, wherein the heat exchanger is configured to heat an oxidizing fluid during use; a conduit disposed in the openhig, wherein the conduit is configured to provide the heated oxidizing fluid from the heat exchanger to at least a portion of the foimation during use, wherein the system is configured to allow heat to fransfer from the heated oxidizing fluid to at least the portion of the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at a reaction zone in the foimation during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2642. The system ofclaim 2641, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2643. The system ofclaim 2641, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.
2644. The system ofclaim 2641, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.
2645. The system ofclaim 2641, wherein the conduit is further configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2646. The system ofclaim 2641, wherehi the conduit is further configured to remove an oxidation product.
2647. The system ofclaim 2641, wherein the conduit is further configured to remove an oxidation product, such that the oxidation product transfers heat to the oxidizing fluid.
2648. The system ofclaim 2641, wherein the conduit is further configured to remove an oxidation product, and wherehi a flow rate of the oxidizing fluid in the conduit is approxhnately equal to a flow rate of the oxidation product in the conduit.
2649. The system ofclaim 2641, wherein the conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizhig fluid in the conduit and a pressure of the oxidation product in the conduit are confrolled to reduce contamination of the oxidation product by the oxidizing fluid.
2650. The system ofclaim 2641, wherein the conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the foπnation beyond the reaction zone.
2651. The system of claim 2641 , wherein the oxidizing fluid is substantially inhibited from flowing into portions of the foπnation beyond the reaction zone.
2652. The system of clahn 2641, further comprising a center conduit disposed within the conduit, wherehi the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configured to remove an oxidation product during use.
2653. The system ofclaim 2641, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2654. The system of claim 2641 , further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2655. The system ofclaim 2641, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2656. The system ofclaim 2641, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2657. The system ofclaim 2641, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2658. The system ofclaim 2641, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2659. The system ofclaim 2641, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2660. A system configurable to heat a relatively low peπneability formation containing heavy hydrocarbons, comprising: a heat exchanger configurable to be disposed external to the formation, wherein the heat exchanger is further configurable to heat an oxidizhig fluid during use; a conduit configurable to be disposed in the opening, wherein the conduit is further configurable to provide the heated oxidizing fluid from the heat exchanger to at least a portion of the formation during use, wherein the system is configurable to allow heat to transfer from the heated oxidizing fluid to at least the portion of the formation during use, and wherein the system is further configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at a reaction zone in the fonnation during use such that heat is generated at the reaction zone; and wherein the system is further configurable to allow heat to ttansfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2661. The system ofclaim 2660, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
2662. The system ofclaim 2660, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.
2663. The system ofclaim 2660, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.
2664. The system ofclaim 2660, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.
2665. The system ofclaim 2660, wherein the conduit is further configurable to remove an oxidation product.
2666. The system ofclaim 2660, wherein the conduit is further configurable to remove an oxidation product such that the oxidation product transfers heat to the oxidizing fluid.
2667. The system ofclaim 2660, wherein the conduit is fuither configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approxhnately equal to a flow rate of the oxidation product in the conduit.
2668. The system of clahn 2660, wherein the conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are confrolled to reduce contamination of the oxidation product by the oxidizing fluid.
2669. The system of claim 2660, wherein the conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the foπnation beyond the reaction zone.
2670. The system ofclaim 2660, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the foπnation beyond the reaction zone.
2671. The system of claim 2660, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the second conduit is further configurable to remove an oxidation product during use.
2672. The system of claim 2660, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2673. The system ofclaim 2660, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foimation.
2674. The system ofclaim 2660, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2675. The system ofclaim 2660, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2676. The system ofclaim 2660, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2677. The system of clahn 2660, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the openmg, and wherehi the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2678. The system ofclaim 2660, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2679. The system ofclaim 2660, wherein the system is configured to heat a relatively low permeability foimation containing heavy hydrocarbons, and wherein the system comprises: a heat exchanger disposed external to the formation, wherein the heat exchanger is configured to heat an oxidizing fluid during use; a conduit disposed in the opening, wherein the conduit is configured to provide the heated oxidizing fluid from the heat exchanger to at least a portion of the fonnation during use, wherein the system is configured to allow heat to fransfer from the heated oxidizing fluid to at least the portion of the foimation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at a reaction zone in the foπnation during use such that heat is generated at the reaction zone; and wherein the system is configured to allow heat to fransfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.
2680. An in situ method for heating a relatively low peπneability formation containing heavy hydrocarbons, comprising: heating a portion of the foimation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid, wherein heating comprises: heating the oxidizhig fluid with a heat exchanger, wherein the heat exchanger is disposed external to the formation; providing the heated oxidizing fluid from the heat exchanger to the portion of the formation; and allowing heat to ttansfer from the heated oxidizing fluid to the portion of the formation; providing the oxidizhig fluid to a reaction zone in the formation; allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and transferring the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the fonnation.
2681. The method of claim 2680, further comprising fransporting the oxidizing fluid through the reaction zone by diffusion.
2682. The method of clahn 2680, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.
2683. The method of clahn 2680, further comprising confrolling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is confrolled.
2684. The method of clahn 2680, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.
2685. The method of claim 2680, wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.
2686. The method ofclaim 2680, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.
2687. The method of claim 2680, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the foimation through the conduit and fransfening heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.
2688. The method ofclaim 2680, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2689. The method ofclaim 2680, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the foπnation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.
2690. The method of claim 2680, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the fonnation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.
2691. The method of claim 2680, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.
2692. The method ofclaim 2680, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.
2693. The method of clahn 2680, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2694. The method of claim 2680, fuither comprising removing water from the formation prior to heating the portion.
2695. The method of claim 2680, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.
2696. The method ofclaim 2680, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2697. The method ofclaim 2680, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2698. The method ofclaim 2680, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2699. The method of claim 2680, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the openhig.
2700. The method of claim 2680, wherein the pyrolysis zone is substantially adjacent to the reaction zone.
2701. An in situ method for heating a relatively low permeability foimation containing heavy hydrocarbons, comprising: heating a portion of the foimation to a temperature sufficient to support reaction of hydrocarbons within the portion of the foimation with an oxidizing fluid, wherein heating comprises: oxidizing a fuel gas in a heater, wherein the heater is disposed external to the foimation; providing the oxidized fuel gas from the heater to the portion of the formation; and allowing heat to transfer from the oxidized fuel gas to the portion of the formation; providing the oxidizing fluid to a reaction zone in the formation; allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and transfening the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.
2702. The method of claim 2701, further comprising fransporting the oxidizing fluid through the reaction zone by diffusion.
2703. The method of clahn 2701, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.
2704. The method ofclaim 2701, further comprising confrolling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is confrolled.
2705. The method ofclaim 2701, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.
2706. The method of claim 2701 , wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.
2707. The method ofclaim 2701, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the foπnation through the conduit.
2708. The method of claim 2701 , wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and transfening heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.
2709. The method ofclaim 2701, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.
2710. The method of claim 2701 , wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and confroUhig a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.
2711. The method of claim 2701, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the foπnation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.
2712. The method of claim 2701 , further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.
2713. The method of claim 2701 , wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.
2714. The method of clahn 2701, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.
2715. The method of claim 2701 , further comprising removing water from the formation prior to heating the portion.
2716. The method ofclaim 2701, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nifrogen during oxidation.
2717. The method ofclaim 2701, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2718. The method ofclaim 2701, fuither comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2719. The method ofclaim 2701, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing is further disposed in cement.
2720. The method ofclaim 2701, further comprising coupling an overburden cashig to the openhig, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
2721. The method of claim 2701 , wherein the pyrolysis zone is substantially adj acent to the reaction zone.
2722. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: an insulated conductor disposed within an open wellbore in the formation, wherein the insulated conductor is configured to provide radiant heat to at least a portion of the formation during use; and wherein the system is configured to allow heat to transfer from the insulated conductor to a selected section of the formation during use.
2723. The system ofclaim 2722, wherein the insulated conductor is further configured to generate heat during application of an elecfrical cunent to the insulated conductor during use.
2724. The system of clahn 2722, further comprising a support member, wherein the support member is configured to support the insulated conductor.
2725. The system ofclaim 2722, further comprising a support member and a centralizer, wherein the support member is configured to support the insulated conductor, and wherein the cenfralizer is configured to maintain a location of the insulated conductor on the support member.
2726. The system ofclaim 2722, wherein the open wellbore comprises a diameter of at least approximately 5 cm.
2727. The system ofclaim 2722, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
2728. The system of claim 2722, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a rubber insulated conductor.
2729. The system ofclaim 2722, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a copper wire.
2730. The system ofclaim 2722, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin fransition conductor.
2731. The system of claim 2722, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor, wherein the cold pin fransition conductor comprises a substantially low resistance insulated conductor.
2732. The system ofclaim 2722, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the electrically insulating material is disposed in a sheath.
2733. The system ofclaim 2722, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the conductor comprises a copper-nickel alloy.
2734. The system ofclaim 2722, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper- nickel alloy comprises approxhnately 7 % nickel by weight to approximately 12 % nickel by weight.
2735. The system ofclaim 2722, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper- nickel alloy comprises approximately 2 % nickel by weight to approximately 6 % nickel by weight.
2736. The system ofclaim 2722, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the electrically insulating material comprises a thermally conductive material.
2737. The system ofclaim 2722, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.
2738. The system of claim 2722, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.
2739. The system ofclaim 2722, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.
2740. The system ofclaim 2722, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.
2741. The system ofclaim 2722, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the elecfrically insulating material is disposed in a sheath, and wherein the sheath comprises a conosion-resistant material.
2742. The system ofclaim 2722, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the elecfrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.
2743. The system ofclaim 2722, further comprising two additional insulated conductors, wherehi the insulated conductor and the two additional insulated conductors are configured in a 3-phase Y configuration.
2744. The system ofclaim 2722, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configured in a series electrical configuration.
2745. The system ofclaim 2722, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configured in a parallel electrical configuration.
2746. The system ofclaim 2722, wherein the insulated conductor is configured to generate radiant heat of approximately 500 W/m to approxhnately 1150 W/m during use.
2747. The system ofclaim 2722, further comprishig a support member configured to support the insulated conductor, wherehi the support member comprises orifices configured to provide fluid flow through the support member into the open wellbore during use.
2748. The system of claim 2722, further comprishig a support member configured to support the insulated conductor, wherein the support member comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the open wellbore during use.
2749. The system of claim 2722, further comprising a tube coupled to the insulated conductor, wherein the tube is configured to provide a flow of fluid into the open wellbore during use.
2750. The system of claim 2722, further comprising a tube coupled to the insulated conductor, wherein the tube comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the open wellbore during use.
2751. The system ofclaim 2722, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the foimation.
2752. The system ofclaim 2722, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2753. The system ofclaim 2722, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2754. The system ofclaim 2722, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packhig material is disposed at ajunction of the overburden casing and the open wellbore.
2755. The system ofclaim 2722, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the open wellbore, and wherein the packing material is configured to substantially inhibit a flow of fluid between the open wellbore and the overburden casing during use.
2756. The system of claim 2722, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the foπnation, wherein a packing material is disposed at a junction of the overburden casing and the open wellbore, and wherein the packing material comprises cement.
2757. The system of claim 2722, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configured to couple to the lead-in conductor.
2758. The system of claim 2722, wherein the system is further configured to transfer heat such that the fransfened heat can pyrolyze at least some of the hydrocarbons in the selected section.
2759. A system configurable to heat a relatively low permeability foimation containing heavy hydrocarbons, comprising: an insulated conductor configurable to be disposed within an open wellbore in the formation, wherein the insulated conductor is further configurable to provide radiant heat to at least a portion of the formation during use; and wherein the system is configurable to allow heat to transfer from the insulated conductor to a selected section of the formation during use.
2760. The system ofclaim 2759, wherein the insulated conductor is further configurable to generate heat during application of an elecfrical cunent to the insulated conductor during use.
2761. The system of claim 2759, further comprising a support member, wherein the support member is configurable to support the insulated conductor.
2762. The system ofclaim 2759, further comprising a support member and a cenfralizer, wherein the support member is configurable to support the insulated conductor, and wherein the centralizer is configurable to maintain a location of the insulated conductor on the support member.
2763. The system ofclaim 2759, wherein the open wellbore comprises a diameter of at least approximately 5 cm.
2764. The system of clahn 2759, further comprismg a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.
2765. The system ofclaim 2759, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a rubber insulated conductor.
2766. The system ofclaim 2759, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a copper wire.
2767. The system ofclaim 2759, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor.
2768. The system of claim 2759, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor, wherein the cold pin fransition conductor comprises a substantially low resistance insulated conductor.
2769. The system ofclaim 2759, wherehi the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material is disposed in a sheath.
2770. The system ofclaim 2759, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the conductor comprises a copper-nickel alloy.
2771. The system ofclaim 2759, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper- nickel alloy comprises approximately 7 % nickel by weight to approximately 12 % nickel by weight.
2772. The system ofclaim 2759, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper- nickel alloy comprises approximately 2 % nickel by weight to approximately 6 % nickel by weight.
2773. The system ofclaim 2759, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the elecfrically insulating material comprises a thennally conductive material.
2774. The system ofclaim 2759, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the elecfrically insulating material comprises magnesium oxide.
2775. The system ofclaim 2759, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the elecfrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.
2776. The system ofclaim 2759, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the elecfrically insulating material comprises aluminum oxide and magnesium oxide.
2777. The system of claim 2759, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the elecfrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configurable to occupy porous spaces within the magnesium oxide.
2778. The system ofclaim 2759, wherehi the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material is disposed in a sheath, and wherein the sheath comprises a conosion-resistant material.
2779. The system ofclaim 2759, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.
2780. The system ofclaim 2759, further comprising two additional insulated conductors, wherein the insulated conductor and the two additional insulated conductors are configurable in a 3 -phase Y configuration.
2781. The system of claim 2759, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configurable in a series elecfrical configuration.
2782. The system ofclaim 2759, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configurable in a parallel electrical configuration.
2783. The system of claim 2759, wherein the insulated conductor is configurable to generate radiant heat of approxhnately 500 W/m to approximately 1150 W/m during use.
2784. The system ofclaim 2759, further comprising a support member configurable to support the insulated conductor, wherein the support member comprises orifices configurable to provide fluid flow through the support member into the open wellbore during use.
2785. The system of claim 2759, further comprising a support member configurable to support the msulated conductor, wherein the support member comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the open wellbore during use.
2786. The system of claim 2759, further comprising a tube coupled to the insulated conductor, wherein the tube is configurable to provide a flow of fluid into the open wellbore during use.
2787. The system of claim 2759, further comprising a tube coupled to the first insulated conductor, wherein the tube comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the open wellbore during use.
2788. The system ofclaim 2759, further comprising an overburden casing coupled to the open wellbore, wherehi the overburden casing is disposed in an overburden of the formation.
2789. The system of claim 2759, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2790. The system ofclaim 2759, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2791. The system of claim 2759, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at ajunction of the overburden casing and the open wellbore.
2792. The system of clahn 2759, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the open wellbore, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the open wellbore and the overburden casing during use.
2793. The system of claim 2759, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the open wellbore, and wherein the packing material comprises cement.
2794. The system ofclaim 2759, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configurable to couple to the lead-in conductor.
2795. The system of claim 2759, wherein the system is further configured to ttansfer heat such that the transfened heat can pyrolyze at least some hydrocarbons in the selected section.
2796. The system of claim 2759, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: an insulated conductor disposed within an open wellbore in the fonnation, wherein the insulated conductor is configured to provide radiant heat to at least a portion of the formation during use; and wherein the system is configured to allow heat to transfer from the insulated conductor to a selected section of the formation during use.
2797. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: applying an electrical current to an insulated conductor to provide radiant heat to at least a portion of the formation, wherein the insulated conductor is disposed within an open wellbore in the formation; and allowing the radiant heat to ttansfer from the insulated conductor to a selected section of the formation.
2798. The method of clahn 2797, further comprising supporting the insulated conductor on a support member.
2799. The method of claim 2797, further comprising supporting the insulated conductor on a support member and maintaining a location of the insulated conductor on the support member with a cenfralizer.
2800. The method of claim 2797, wherein the insulated conductor is coupled to two additional insulated conductors, wherein the insulated conductor and the two insulated conductors are disposed within the open wellbore, and wherein the three insulated conductors are elecfrically coupled in a 3-phase Y configuration.
2801. The method of claim 2797, wherein an additional insulated conductor is disposed within the open wellbore.
2802. The method ofclaim 2797, wherein an additional insulated conductor is disposed within the open wellbore, and wherein the insulated conductor and the additional insulated conductor are elecfrically coupled in a series configuration.
2803. The method of claim 2797, wherein an additional insulated conductor is disposed within the open wellbore, and wherein the insulated conductor and the additional insulated conductor are electrically coupled in a parallel configuration.
2804. The method ofclaim 2797, wherein the provided heat comprises approximately 500 W/m to approximately 1150 W/m.
2805. The method of claim 2797, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the conductor comprises a copper-nickel alloy.
2806. The method of claim 2797, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper- nickel alloy comprises approximately 7 % nickel by weight to approximately 12 % nickel by weight.
2807. The method of claim 2797, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper- nickel alloy comprises approximately 2 % nickel by weight to approximately 6 % nickel by weight.
2808. The method of clahn 2797, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.
2809. The method of claim 2797, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherehi the magnesium oxide comprises a thickness of at least approximately 1 mm.
2810. The method of clahn 2797, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material comprises aluminum oxide and magnesium oxide.
2811. The method of claim 2797, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the elecfrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.
2812. The method of claim 2797, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises a conosion-resistant material.
2813. The method ofclaim 2797, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.
2814. The method of claim 2797, further comprising supporting the insulated conductor on a support member and flowing a fluid into the open wellbore through an orifice in the support member.
2815. The method ofclaim 2797, further comprising supporting the insulated conductor on a support member and flowing a substantially constant amount of fluid into the open wellbore through critical flow orifices in the support member.
2816. The method ofclaim 2797, wherein a perforated tube is disposed in the open wellbore proxunate to the insulated conductor, the method further comprising flowing a fluid into the open wellbore through the perforated tube.
2817. The method of claim 2797, wherein a tube is disposed in the open wellbore proximate to the insulated conductor, the method further comprising flowing a substantially constant amount of fluid into the open wellbore through critical flow orifices in the tube.
2818. The method of claim 2797, further comprising supporting the insulated conductor on a support member and flowing a conosion inhibiting fluid into the open wellbore through an orifice in the support member.
2819. The method ofclaim 2797, wherein a perforated tube is disposed in the open wellbore proximate to the insulated conductor, the method further comprising flowing a conosion inhibiting fluid into the open wellbore through the perforated tube.
2820. The method of claim 2797, further comprising determining a temperature distribution in the insulated conductor using an electromagnetic signal provided to the insulated conductor.
2821. The method ofclaim 2797, fuither comprising monitoring a leakage cunent of the insulated conductor.
2822. The method of clahn 2797, further comprising monitoring the applied electrical cunent.
2823. The method ofclaim 2797, further comprising monitoring a voltage applied to the insulated conductor.
2824. The method of claim 2797, further comprising monitoring a temperature in the insulated conductor with at least one thermocouple.
2825. The method of claim 2797, further comprising electrically coupling a lead-in conductor to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
2826. The method ofclaim 2797, further comprising electrically coupling a lead-in conductor to the insulated conductor using a cold pin fransition conductor.
2827. The method ofclaim 2797, further comprising electrically coupling a lead-in conductor to the insulated conductor using a cold pin transition conductor, wherein the cold pin fransition conductor comprises a substantially low resistance insulated conductor.
2828. The method ofclaim 2797, further comprising coupling an overburden casing to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation.
2829. The method of claim 2797, further comprising coupling an overburden casing to the open wellbore, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing comprises steel.
2830. The method ofclaim 2797, further comprising coupling an overburden casing to the open wellbore, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing is further disposed in cement.
2831. The method of claim 2797, further comprising coupling an overburden casing to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at ajunction of the overburden casing and the open wellbore.
2832. The method of claim 2797, further comprising coupling an overburden casing to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the open wellbore and the overburden cashig with a packing material.
2833. The method ofclaim 2797, further comprising heating at least the portion of the foπnation to pyrolyze at least some hydrocarbons within the formation.
2834. An in situ method for heating a relatively low peπneability formation containing heavy hydrocarbons, comprising: applying an elecfrical cunent to an insulated conductor to provide heat to at least a portion of the foπnation, wherein the insulated conductor is disposed within an openhig in the formation; and allowing the heat to fransfer from the insulated conductor to a section of the fonnation.
2835. The method ofclaim 2834, further comprising supporting the insulated conductor on a support member.
2836. The method ofclaim 2834, further comprising supporting the insulated conductor on a support member and maintaining a location of the first insulated conductor on the support member with a cenfralizer.
2837. The method ofclaim 2834, wherein the insulated conductor is coupled to two additional insulated conductors, wherein the insulated conductor and the two insulated conductors are disposed within the opening, and wherein the three insulated conductors are electrically coupled in a 3-phase Y configuration.
2838. The method ofclaim 2834, wherein an additional insulated conductor is disposed within the openhig.
2839. The method ofclaim 2834, wherein an additional insulated conductor is disposed within the opening, and wherein the insulated conductor and the additional insulated conductor are electrically coupled in a series configuration.
2840. The method o claim 2834, wherein an additional insulated conductor is disposed within the opening, and wherein the insulated conductor and the additional insulated conductor are elecfrically coupled in a parallel configuration.
2841. The method of claim 2834, wherein the provided heat comprises approximately 500 W/m to approximately 1150 W/m.
2842. The method ofclaim 2834, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the conductor comprises a copper-nickel alloy.
2843. The method ofclaim 2834, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper- nickel alloy comprises approximately 7 % nickel by weight to approximately 12 % nickel by weight.
2844. The method of clahn 2834, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper- nickel alloy comprises approximately 2 % nickel by weight to approximately 6 % nickel by weight.
2845. The method of claim 2834, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material comprises magnesium oxide.
2846. The method of clahn 2834, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the elecfrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.
2847. The method of claim 2834, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material comprises aluminum oxide and magnesium oxide.
2848. The method of claim 2834, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.
2849. The method ofclaim 2834, wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises a conosion-resistant material.
2850. The method ofclaim 2834, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.
2851. The method of claim 2834, further comprising supporting the insulated conductor on a support member and flowing a fluid into the opening through an orifice in the support member.
2852. The method of claim 2834, further comprising supporting the insulated conductor on a support member and flowing a substantially constant amount of fluid into the opening through critical flow orifices in the support member.
2853. The method of claim 2834, wherein a perforated tube is disposed in the opening proxhnate to the insulated conductor, the method further comprishig flowing a fluid into the opening through the perforated tube.
2854. The method of claim 2834, wherein a tube is disposed in the opening proximate to the insulated conductor, the method further comprising flowing a substantially constant amount of fluid into the opening through critical flow orifices in the tube.
2855. The method of claim 2834, fuither comprising supporting the insulated conductor on a support member and flowing a conosion inhibiting fluid into the opening through an orifice in the support member.
2856. The method of claim 2834, wherein a perforated tube is disposed in the opening proxhnate to the insulated conductor, the method further comprishig flowing a conosion inhibiting fluid into the opening through the perforated tube.
2857. The method of clahn 2834, further comprishig deteπnining a temperature disttibution in the insulated conductor using an electromagnetic signal provided to the insulated conductor.
2858. The method ofclaim 2834, further comprising monitoring a leakage cunent of the insulated conductor.
2859. The method ofclaim 2834, further comprising monitoring the applied elecfrical cunent.
2860. The method ofclaim 2834, further comprising monitoring a voltage applied to the insulated conductor.
2861. The method of claim 2834, further comprising monitoring a temperature in the insulated conductor with at least one thermocouple.
2862. The method of claim 2834, further comprising electrically coupling a lead-in conductor to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
2863. The method ofclaim 2834, further comprising electrically coupling a lead-in conductor to the insulated conductor using a cold pin fransition conductor.
2864. The method ofclaim 2834, further comprising electrically coupling a lead-in conductor to the insulated conductor using a cold pin fransition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.
2865. The method ofclaim 2834, further comprising coupling an overburden cashig to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2866. The method of claim 2834, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2867. The method of clahn 2834, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing is further disposed in cement.
2868. The method of claim 2834, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
2869. The method of clahn 2834, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.
2870. The method of claim 2834, further comprising heating at least the portion of the foπnation to substantially pyrolyze at least some hydrocarbons within the foπnation.
2871. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: an insulated conductor disposed withhi an opening in the formation, wherein the insulated conductor is configured to provide heat to at least a portion of the formation during use, wherein the insulated conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7 % nickel by weight to approximately 12 % nickel by weight; and wherein the system is configured to allow heat to ttansfer from the insulated conductor to a selected section of the foπnation during use.
2872. The system ofclaim 2871, wherein the insulated conductor is further configured to generate heat during application of an elecfrical cunent to the insulated conductor during use.
2873. The system ofclaim 2871, further comprismg a support member, wherein the support member is configured to support the insulated conductor.
2874. The system ofclaim 2871, further comprising a support member and a cenfralizer, wherein the support member is configured to support the insulated conductor, and wherem the cenfralizer is configured to maintain a location of the insulated conductor on the support member.
2875. The system ofclaim 2871, wherein the opening comprises a diameter of at least approximately 5 cm.
2876. The system ofclaim 2871, further comprising a lead-in conductor coupled to the insulated conductor, wherehi the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
2877. The system ofclaim 2871, further comprismg a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a rubber insulated conductor.
2878. The system ofclaim 2871, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a copper wire.
2879. The system ofclaim 2871, fuither comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor.
2880. The system ofclaim 2871, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin fransition conductor, wherein the cold pin fransition conductor comprises a substantially low resistance insulated conductor.
2881. The system ofclaim 2871, wherein the copper-nickel alloy is disposed in an elecfrically insulating material, and wherein the electrically insulating material comprises a thermally conductive material.
2882. The system ofclaim 2871, wherein the copper-nickel alloy is disposed in an elecfrically insulating material, and wherein the elecfrically insulating material comprises magnesium oxide.
2883. The system ofclaim 2871, wherein the copper-nickel alloy is disposed in an elecfrically insulating material, wherein the elecfrically insulating material comprises magnesium oxide, and wherein the magnesimn oxide comprises a thickness of at least approximately 1 mm.
2884. The system of claim 2871 , wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the elecfrically insulating material comprises aluminum oxide and magnesium oxide.
2885. The system ofclaim 2871, wherein the copper-nickel alloy is disposed in an elecfrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherehi the grain particles are configured to occupy porous spaces within the magnesium oxide.
2886. The system ofclaim 2871, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises a conosion-resistant material.
2887. The system ofclaim 2871, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.
2888. The system ofclaim 2871, further comprising two additional insulated conductors, wherein the insulated conductor and the two additional insulated conductors are configured in a 3-phase Y configuration.
2889. The system ofclaim 2871, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configured in a series electrical configuration.
2890. The system ofclaim 2871, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configured in a parallel electrical configuration.
2891. The system ofclaim 2871, wherein the insulated conductor is configured to generate radiant heat of approximately 500 W/m to approximately 1150 W/m during use.
2892. The system ofclaim 2871, further comprising a support member configured to support the insulated conductor, wherein the support member comprises orifices configured to provide fluid flow through the support member into the opening during use.
2893. The system of claim 2871 , further comprising a support member configured to support the insulated conductor, wherein the support member comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the opening during use.
2894. The system of claim 2871 , further comprising a tube coupled to the insulated conductor, wherein the tube is configured to provide a flow of fluid into the opening during use.
2895. The system of claim 2871 , further comprising a tube coupled to the insulated conductor, wherein the tube comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the opening during use.
2896. The system ofclaim 2871, further comprising an overburden casing coupled to the openhig, wherein the overburden casing is disposed in an overburden of the formation.
2897. The system ofclaim 2871, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2898. The system ofclaim 2871, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2899. The system of claim 2871, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherehi a packing material is disposed at a junction of the overburden casing and the opening.
2900. The system ofclaim 2871, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a
junction of the overburden casing and the openmg, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2901. The system ofclaim 2871, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden cashig and the opening, and wherein the packing material comprises cement.
2902. The system ofclaim 2871, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configured to couple to the lead-in conductor.
2903. The system ofclaim 2871, wherein the system is further configured to fransfer heat such that the fransfened heat can pyrolyze at least some hydrocarbons in the selected section.
2904. A system configurable to heat a relatively low permeability foπnation containing heavy hydrocarbons, comprising: an insulated conductor configurable to be disposed within an opening in the formation, wherein the insulated conductor is further configurable to provide heat to at least a portion of the foimation during use, wherein the insulated conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7 % nickel by weight to approximately 12 % nickel by weight; wherein the system is configurable to allow heat to fransfer from the insulated conductor to a selected section of the formation during use.
2905. The system ofclaim 2904, wherein the insulated conductor is further configurable to generate heat during application of an electrical cunent to the insulated conductor during use.
2906. The system of claim 2904, further comprising a support member, wherein the support member is configurable to support the insulated conductor.
2907. The system ofclaim 2904, further comprising a support member and a cenfralizer, wherein the support member is configurable to support the insulated conductor, and wherein the centtalizer is configurable to maintain a location of the insulated conductor on the support member.
2908. The system ofclaim 2904, wherein the opening comprises a diameter of at least approxhnately 5 cm.
2909. The system ofclaim 2904, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.
2910. The system ofclaim 2904, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a rubber insulated conductor.
2911. The system of clahn 2904, further comprishig a lead-hi conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a copper wire.
2912. The system ofclaim 2904, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor.
2913. The system ofclaim 2904, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor, wherein the cold pin fransition conductor comprises a substantially low resistance insulated conductor.
2914. The system ofclaim 2904, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electtically insulating material comprises a thermally conductive material.
2915. The system ofclaim 2904, wherein the copper-nickel alloy is disposed in an elecfrically insulating material, and wherein the elecfrically insulating material comprises magnesium oxide.
2916. The system ofclaim 2904, wherem the copper-nickel alloy is disposed in an elecfrically insulating material, wherein the elecfrically insulating material comprises magnesimn oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.
2917. The system ofclaim 2904, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electtically insulating material comprises aluminum oxide and magnesium oxide.
2918. The system ofclaim 2904, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electtically insulating material comprises magnesium oxide, wherein the magnesimn oxide comprises grain particles, and wherein the grain particles are configurable to occupy porous spaces within the magnesium oxide.
2919. The system ofclaim 2904, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the elecfrically insulating material is disposed in a sheath, and wherein the sheath comprises a conosion-resistant material.
2920. The system ofclaim 2904, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the elecfrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.
2921. The system of claim 2904, further comprising two additional insulated conductors, wherein the insulated conductor and the two additional insulated conductors are configurable in a 3-phase Y configuration.
2922. The system ofclaim 2904, further comprising an additional insulated conductor, wherehi the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configurable in a series elecfrical configuration.
2923. The system ofclaim 2904, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configurable in a parallel elecfrical configuration.
2924. The system of claim 2904, wherein the insulated conductor is configurable to generate radiant heat of approxhnately 500 W/m to approximately 1 150 W/m during use.
2925. The system ofclaim 2904, further comprising a support member configurable to support the insulated conductor, wherein the support member comprises orifices configurable to provide fluid flow through the support member into the open wellbore during use.
2926. The system of claim 2904, further comprising a support member configurable to support the insulated conductor, wherein the support member comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the opening during use.
2927. The system of claim 2904, further comprising a tube coupled to the insulated conductor, wherein the tube is configurable to provide a flow of fluid into the opening during use.
2928. The system of claim 2904, further comprising a tube coupled to the insulated conductor, wherein the tube comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the opening during use.
2929. The system ofclaim 2904, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
2930. The system of claim 2904, further comprising an overburden cashig coupled to the opening, wherein the overburden cashig is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2931. The system ofclaim 2904, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2932. The system ofclaim 2904, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
2933. The system ofclaim 2904, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
2934. The system ofclaim 2904, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
2935. The system ofclaim 2904, further comprising an overburden casing coupled to the opening, wherein the overburden cashig is disposed in an overburden of the foπnation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configurable to couple to the lead-in conductor.
2936. The system ofclaim 2904, wherein the system is further configured to fransfer heat such that the fransfened heat can pyrolyze at least some hydrocarbons in the selected section.
2937. The system of claim 2904, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: an insulated conductor disposed within an opening in the foimation, wherein the insulated conductor is configured to provide heat to at least a portion of the formation during use, wherein the insulated conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7 % nickel by weight to approximately 12 % nickel by weight; and wherein the system is configured to allow heat to fransfer from the insulated conductor to a selected section of the formation during use.
2938. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: applying an elecfrical cunent to an insulated conductor to provide heat to at least a portion of the formation, wherein the insulated conductor is disposed within an opening in the foimation, and wherein the insulated conductor comprises a copper-nickel alloy of approximately 7 % nickel by weight to approximately 12 % nickel by weight; and allowing the heat to ttansfer from the insulated conductor to a selected section of the formation.
2939. The method of claim 2938, further comprising supporting the insulated conductor on a support member.
2940. The method ofclaim 2938, further comprising supporting the insulated conductor on a support member and maintaining a location of the first insulated conductor on the support member with a centralizer.
2941. The method of claim 2938, wherein the insulated conductor is coupled to two additional insulated conductors, wherein the insulated conductor and the two insulated conductors are disposed within the opening, and wherein the three insulated conductors are electrically coupled in a 3-phase Y configuration.
2942. The method ofclaim 2938, wherein an additional insulated conductor is disposed within the opening.
2943. The method of claim 2938, wherein an additional insulated conductor is disposed within the opening, and wherehi the insulated conductor and the additional insulated conductor are electrically coupled in a series configuration.
2944. The method ofclaim 2938, wherein an additional insulated conductor is disposed within the opening, and wherein the insulated conductor and the additional insulated conductor are elecfrically coupled in a parallel configuration.
2945. The method ofclaim 2938, wherein the provided heat comprises approximately 500 W/m to approximately 1150 W/m.
2946. The method ofclaim 2938, wherehi the copper-nickel alloy is disposed in an elecfrically insulating material.
2947. The method ofclaim 2938, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.
2948. The method of claim 2938, wherein the copper-nickel alloy is disposed in an elecfrically insulating material, wherein the elecfrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.
2949. The method of claim 2938, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the elecfrically insulating material comprises aluminum oxide and magnesium oxide.
2950. The method ofclaim 2938, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the elecfrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.
2951. The method of claim 2938, wherein the copper-nickel alloy is disposed in an elecfrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises a conosion- resistant material.
2952. The method of claim 2938, wherein the copper-nickel alloy is disposed in an elecfrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.
2953. The method of claim 2938, further comprising supporting the insulated conductor on a support member and flowing a fluid into the opening through an orifice in the support member.
2954. The method ofclaim 2938, further comprising supporting the insulated conductor on a support member and flowing a substantially constant amount of fluid into the opening through critical flow orifices in the support member.
2955. The method of clahn 2938, wherein a perforated tube is disposed in the opening proximate to the insulated conductor, the method further comprising flowing a fluid into the opening through the perforated tube.
2956. The method ofclaim 2938, wherein a tube is disposed in the opening proxhnate to the insulated conductor, the method further comprising flowing a substantially constant amount of fluid into the opening through critical flow orifices in the tube.
2957. The method of claim 2938, further comprising supporting the insulated conductor on a support member and flowing a conosion inhibiting fluid into the opening through an orifice in the support member.
2958. The method ofclaim 2938, wherein a perforated tube is disposed in the opening proximate to the insulated conductor, the method further comprising flowing a conosion inhibiting fluid into the opening through the perforated tube.
2959. The method ofclaim 2938, further comprising determining a temperature disfribution in the insulated conductor using an electromagnetic signal provided to the insulated conductor.
2960. The method ofclaim 2938, further comprising monitoring a leakage cunent of the insulated conductor.
2961. The method of claim 2938, further comprising monitoring the applied electrical cunent.
2962. The method of clahn 2938, further comprising monitoring a voltage applied to the insulated conductor.
2963. The method of claim 2938, further comprising monitoring a temperature in the insulated conductor with at least one theπnocouple.
2964. The method ofclaim 2938, further comprising elecfrically coupling a lead-in conductor to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
2965. The method of claim 2938, further comprising elecfrically coupling a lead-in conductor to the insulated conductor using a cold pin fransition conductor.
2966. The method ofclaim 2938, further comprising elecfrically coupling a lead-in conductor to the insulated conductor using a cold pin fransition conductor, wherein the cold pin fransition conductor comprises a substantially low resistance insulated conductor.
2967. The method ofclaim 2938, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the fonnation.
2968. The method of claim 2938, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
2969. The method of claim 2938, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
2970. The method of claim 2938, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the fonnation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
2971. The method ofclaim 2938, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.
2972. The method of clahn 2938, further comprising heating at least the portion of the formation to substantially pyrolyze at least some hydrocarbons within the formation.
2973. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprismg: at least three insulated conductors disposed within an opening in the foπnation, wherein at least the three insulated conductors are electtically coupled in a 3-phase Y configuration, and wherein at least the three insulated conductors are configured to provide heat to at least a portion of the foπnation during use; and wherein the system is configured to allow heat to fransfer from at least the three insulated conductors to a selected section of the formation during use.
2974. The system ofclaim 2973, wherein at least the three insulated conductors are further configured to generate heat during application of an elecfrical cunent to at least the three insulated conductors during use.
2975. The system of claim 2973, further comprising a support member, wherein the support member is configured to support at least the three insulated conductors.
2976. The system ofclaim 2973, further comprising a support member and a cenfralizer, wherein the support member is configured to support at least the three insulated conductors, and wherein the cenfralizer is configured to maintain a location of at least the three insulated conductors on the support member.
2977. The system ofclaim 2973, wherein the opening comprises a diameter of at least approximately 5 cm.
2978. The system of claim 2973, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
2979. The system ofclaim 2973, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a rubber insulated conductor.
2980. The system of claim 2973, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a copper wire.
2981. The system of claim 2973, further comprising at least one lead-in conductor coupled to at least the three insulated conductors with a cold pin transition conductor.
2982. The system of claim 2973, further comprising at least one lead-in conductor coupled to at least the three insulated conductors with a cold pin fransition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.
2983. The system ofclaim 2973, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, and wherein the electrically insulating material is disposed in a sheath.
2984. The system of claim 2973, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, and wherein the conductor comprises a copper-nickel alloy.
2985. The system of claim 2973, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7 % nickel by weight to approximately 12 % nickel by weight.
2986. The system ofclaim 2973, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 2 % nickel by weight to approxhnately 6 % nickel by weight.
2987. The system of claim 2973, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, and wherein the elecfrically insulating material comprises a thermally conductive material.
2988. The system ofclaim 2973, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material comprises magnesium oxide.
2989. The system ofclaim 2973, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.
2990. The system ofclaim 2973, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesimn oxide.
2991. The system of claim 2973 , wherein the insulated conductor comprises a conductor disposed in an elecfrically insulating material, wherein the electtically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.
2992. The system ofclaim 2973, wherein at least the three insulated conductors comprise a conductor disposed in an electtically insulating material, and wherein the electtically insulating material is disposed in a sheath, and wherein the sheath comprises a conosion-resistant material.
2993. The system of claim 2973, wherein at least the three insulated conductors comprise a conductor disposed in an electtically insulating material, and wherein the elecfrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.
2994. The system of claim 2973, wherein at least the three insulated conductors are configured to generate radiant heat of approximately 500 W/m to approximately 1150 W/m of at least the three insulated conductors during use.
2995. The system of clahn 2973, further comprising a support member configured to support at least the three insulated conductors, wherein the support member comprises orifices configured to provide fluid flow through the support member into the opening during use.
2996. The system ofclaim 2973, further comprising a support member configured to support at least the three insulated conductors, wherein the support member comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the opening during use.
2997. The system ofclaim 2973, further comprising a tube coupled to at least the three insulated conductors, wherein the tube is configured to provide a flow of fluid into the opening during use.
2998. The system ofclaim 2973, further comprising a tube coupled to at least the three insulated conductors, wherein the tube comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the opening during use.
2999. The system ofclaim 2973, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation.
3000. The system of claim 2973, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the fonnation, and wherein the overburden casing comprises steel.
3001. The system of claim 2973 , further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foimation, and wherein the overburden casing is further disposed in cement.
3002. The system ofclaim 2973, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3003. The system ofclaim 2973, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foimation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
3004. The system ofclaim 2973, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
3005. The system of claim 2973 , further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configured to couple to the lead-in conductor.
3006. The system ofclaim 2973, wherein the system is further configured to fransfer heat such that the transfened heat can pyrolyze at least some hydrocarbons in the selected section.
3007. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: at least three insulated conductors configurable to be disposed within an opening in the formation, wherein at least the three insulated conductors are elecfrically coupled in a 3-phase Y configuration, and wherein at least the three insulated conductors are further configurable to provide heat to at least a portion of the fonnation during use; and wherein the system is configurable to allow heat to ttansfer from at least the three insulated conductors to a selected section of the formation during use.
3008. The system ofclaim 3007, wherein at least the three insulated conductors are further configurable to generate heat during application of an elecfrical cunent to at least the three insulated conductors during use.
3009. The system ofclaim 3007, further comprising a support member, wherein the support member is configurable to support at least the three insulated conductors.
3010. The system ofclaim 3007, further comprising a support member and a cenfralizer, wherein the support member is configurable to support at least the three insulated conductors, and wherein the centralizer is configurable to maintain a location of at least the three insulated conductors on the support member.
3011. The system ofclaim 3007, wherein the opening comprises a diameter of at least approximately 5 cm.
3012. The system ofclaim 3007, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherehi at least the one lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.
3013. The system ofclaim 3007, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a rubber insulated conductor.
3014. The system ofclaim 3007, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a copper wire.
3015. The system ofclaim 3007, further comprising at least one lead-in conductor coupled to at least the three insulated conductors with a cold pin fransition conductor.
3016. The system ofclaim 3007, further comprising at least one lead-in conductor coupled to at least the three insulated conductors with a cold pin fransition conductor, wherein the cold pin fransition conductor comprises a substantially low resistance insulated conductor.
3017. The system ofclaim 3007, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, and wherein the elecfrically insulating material is disposed in a sheath.
3018. The system of clahn 3007, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, and wherein the conductor comprises a copper-nickel alloy.
3019. The system ofclaim 3007, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7 % nickel by weight to approximately 12 % nickel by weight.
3020. The system ofclaim 3007, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 2 % nickel by weight to approximately 6 % nickel by weight.
3021. The system of claim 3007, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material comprises a thermally conductive material.
3022. The system of claim 3007, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material comprises magnesium oxide.
3023. The system ofclaim 3007, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the electtically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.
3024. The system of claim 3007, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material comprises aluminum oxide and magnesium oxide.
3025. The system of claim 3007, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the elecfrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configurable to occupy porous spaces within the magnesium oxide.
3026. The system of clahn 3007, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises a conosion-resistant material.
3027. The system ofclaim 3007, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, and wherein the elecfrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.
3028. The system of claim 3007, wherein at least the three insulated conductors are configurable to generate radiant heat of approximately 500 W/m to approximately 1150 W/m during use.
3029. The system ofclaim 3007, further comprising a support member configurable to support at least the three insulated conductors, wherein the support member comprises orifices configurable to provide fluid flow through the support member into the opening during use.
3030. The system of claim 3007, further comprising a support member configurable to support at least the three insulated conductors, wherein the support member comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the opening during use.
3031. The system of claim 3007, further comprising a tube coupled to at least the three insulated conductors, wherein the tube is configurable to provide a flow of fluid into the opening during use.
3032. The system ofclaim 3007, further comprising a tube coupled to at least the three insulated conductors, wherein the tube comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the openhig during use.
3033. The system ofclaim 3007, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3034. The system ofclaim 3007, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
3035. The system of claim 3007, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
3036. The system of claim 3007, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the openhig.
3037. The system ofclaim 3007, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a
junction of the overburden casing and the opening, and wherehi the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
3038. The system ofclaim 3007, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
3039. The system ofclaim 3007, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed hi an overburden of the fonnation, the system fiirther comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configurable to couple to the lead-in conductor.
3040. The system of claim 3007, wherein the system is further configured to fransfer heat such that the fransfened heat can pyrolyze at least some hydrocarbons in the selected section.
3041. The system ofclaim 3007, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: at least three insulated conductors disposed within an opening in the formation, wherein at least the three insulated conductors are elecfrically coupled in a 3-phase Y configuration, and wherein at least the three insulated conductors are configured to provide heat to at least a portion of the foimation during use; and wherein the system is configured to allow heat to fransfer from at least the three insulated conductors to a selected section of the formation during use.
3042. An in situ method for heating a relatively low permeability foπnation containing heavy hydrocarbons, comprising: applying an electrical cunent to at least three insulated conductors to provide heat to at least a portion of the formation, wherein at least the three insulated conductors are disposed within an opening in the foπnation; and allowing the heat to fransfer from at least the three insulated conductors to a selected section of the formation.
3043. The method ofclaim 3042, further comprising supporting at least the three insulated conductors on a support member.
3044. The method of claim 3042, further comprising supporting at least the three insulated conductors on a support member and maintaining a location of at least the three insulated conductors on the support member with a centralizer.
3045. The method ofclaim 3042, wherein the provided heat comprises approximately 500 W/m to approximately 1150 W/m.
3046. The method ofclaim 3042, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the conductor comprises a copper-nickel alloy.
3047. The method of claim 3042, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7 % nickel by weight to approximately 12 % nickel by weight.
3048. The method ofclaim 3042, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 2 % nickel by weight to approximately 6 % nickel by weight.
3049. The method ofclaim 3042, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, and wherein the elecfrically insulating material comprises magnesium oxide.
3050. The method ofclaim 3042, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the electtically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.
3051. The method of claim 3042, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the elecfrically insulating material comprises aluminum oxide and magnesium oxide.
3052. The method ofclaim 3042, wherein at least the three insulated conductors comprise a conductor disposed in an elecfrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.
3053. The method ofclaim 3042, wherein at least the three insulated conductors comprise a conductor disposed in an electtically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises a conosion-resistant material.
3054. The method of claim 3042, wherein at least the three insulated conductors comprise a conductor disposed in an electtically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.
3055. The method of clahn 3042, further comprising supporting at least the three insulated conductors on a support member and flowing a fluid into the opening through an orifice in the support member.
3056. The method ofclaim 3042, further comprising supporting at least the three insulated conductors on a support member and flowing a substantially constant amount of fluid into the opening through critical flow orifices in the support member.
3057. The method of clahn 3042, wherein a perforated tube is disposed in the opening proximate to at least the three insulated conductors, the method further comprising flowing a fluid into the opening through the perforated tube.
3058. The method of claim 3042, wherein a tube is disposed in the opening proximate to at least the three insulated conductors, the method further comprising flowing a substantially constant amount of fluid into the opening through critical flow orifices in the tube.
3059. The method ofclaim 3042, further comprising supporting at least the three insulated conductors on a support member and flowing a conosion inhibiting fluid into the opening through an orifice in the support member.
3060. The method of claim 3042, wherein a perforated tube is disposed in the opening proximate to at least the three insulated conductors, the method further comprising flowing a conosion inhibiting fluid into the opening through the perforated tube.
3061. The method ofclaim 3042, further comprising determining a temperature disttibution in at least the three insulated conductors using an electromagnetic signal provided to the insulated conductor.
3062. The method of claim 3042, further comprising monitoring a leakage cunent of at least the three insulated conductors.
3063. The method ofclaim 3042, further comprising monitoring the applied elecfrical cunent.
3064. The method of claim 3042, further comprising monitoring a voltage applied to at least the three insulated conductors.
3065. The method ofclaim 3042, further comprising monitoring a temperature in at least the three insulated conductors with at least one thermocouple.
3066. The method of clahn 3042, further comprising electrically coupling a lead-in conductor to at least the three insulated conductors, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
3067. The method of claim 3042, fuither comprising electrically coupling a lead-in conductor to at least the three insulated conductors using a cold pin transition conductor.
3068. The method of claim 3042, further comprising electrically coupling a lead-in conductor to at least the three insulated conductors using a cold pin fransition conductor, wherein the cold pin fransition conductor comprises a substantially low resistance msulated conductor.
3069. The method of claim 3042, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3070. The method of claim 3042, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
3071. The method ofclaim 3042, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing is further disposed in cement.
3072. The method of claim 3042, further comprising couplmg an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3073. The method ofclaim 3042, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.
3074. The method of claim 3042, further comprising heating at least the portion of the formation to substantially pyrolyze at least some of the hydrocarbons within the formation.
3075. A system configured to heat a relatively low permeability foπnation containing heavy hydrocarbons, comprising: a first conductor disposed in a first conduit, wherein the first conduit is disposed within an opening in the foπnation, and wherein the first conductor is configured to provide heat to at least a portion of the foπnation during use; and wherein the system is configured to allow heat to fransfer from the first conductor to a section of the formation during use.
3076. The system ofclaim 3075, wherein the first conductor is further configured to generate heat during application of an elecfrical cunent to the first conductor.
3077. The system ofclaim 3075, wherein the first conductor comprises a pipe.
3078. The system ofclaim 3075, wherein the first conductor comprises stainless steel.
3079. The system ofclaim 3075, wherein the first conduit comprises stainless steel.
3080. The system of claim 3075, further comprising a centralizer configured to maintain a location of the ffrst conductor within the ffrst conduit.
3081. The system of claim 3075, further comprising a cenfralizer configured to maintain a location of the first conductor within the first conduit, wherein the centralizer comprises ceramic material.
3082. The system ofclaim 3075, further comprising a centralizer configured to maintain a location of the first conductor within the first conduit, wherein the cenfralizer comprises ceramic material and stainless steel.
3083. The system ofclaim 3075, wherein the opening comprises a diameter of at least approximately 5 cm.
3084. The system ofclaim 3075, further comprising a lead-in conductor coupled to the first conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
3085. The system ofclaim 3075, further comprising a lead-in conductor coupled to the first conductor, wherein the lead-in conductor comprises copper.
3086. The system of claim 3075, further comprising a sliding electrical connector coupled to the first conductor.
3087. The system ofclaim 3075, further comprising a sliding electrical connector coupled to the first conductor, wherein the sliding electrical connector is further coupled to the first conduit.
3088. The system of claim 3075, further comprising a sliding electrical connector coupled to the first conductor, wherein the sliding electrical connector is further coupled to the first conduit, and wherein the sliding electrical connector is configured to complete an electrical circuit with the first conductor and the first conduit.
3089. The system ofclaim 3075, further comprising a second conductor disposed within the first conduit and at least one sliding electrical connector coupled to the first conductor and the second conductor, wherein at least the one sliding elecfrical connector is configured to generate less heat than the first conductor or the second conductor during use.
3090. The system ofclaim 3075, wherein the first conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.
3091. The system ofclaim 3075, further comprising a fluid disposed within the ffrst conduit, wherein the fluid is configured to maintain a pressure within the first conduit to substantially inhibit deformation of the first conduit during use.
3092. The system of claim 3075, further comprising a thermally conductive fluid disposed withhi the first conduit.
3093. The system ofclaim 3075, further comprising a thennally conductive fluid disposed within the first conduit, wherein the thermally conductive fluid comprises helium.
3094. The system ofclaim 3075, further comprising a fluid disposed within the first conduit, wherein the fluid is configured to substantially inhibit arcing between the first conductor and the first conduit during use.
3095. The system ofclaim 3075, further comprising a tube disposed within the opening external to the first conduit, wherein the tube is configured to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the first conduit and the opening to substantially inhibit deformation of the first conduit during use.
3096. The system of claim 3075, wherein the first conductor is further configured to generate radiant heat of approximately 650 W/ni to approximately 1650 W/m during use.
3097. The system of clahn 3075, further comprising a second conductor disposed within a second conduit and a third conductor disposed within a thfrd conduit, wherein the ffrst conduit, the second conduit and the third conduit are disposed in different openings of the formation, wherein the first conductor is elecfrically coupled to the second conductor and the third conductor, and wherein the first, second, and third conductors are configured to operate in a 3-phase Y configuration during use.
3098. The system of claim 3075, further comprising a second conductor disposed within the first conduit, wherein the second conductor is electrically coupled to the first conductor to form an elecfrical circuit.
3099. The system ofclaim 3075, further comprising a second conductor disposed within the first conduit, wherein the second conductor is elecfrically coupled to the first conductor to form an electrical circuit with a connector.
3100. The system ofclaim 3075, further comprising an overburden casing coupled to the opening, wherein the overburden cashig is disposed in an overburden of the foπnation.
3101. The system ofclaim 3075, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
3102. The system ofclaim 3075, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
3103. The system of clahn 3075, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3104. The system ofclaim 3075, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
3105. The system ofclaim 3075, furtlier comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electtically coupled to the first conductor.
3106. The system of claim 3075, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electtically coupled to the first conductor, and wherein the substantially low resistance conductor comprises carbon steel.
3107. The system ofclaim 3075, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing and a centtalizer configured to support the substantially low resistance conductor within the overburden casing.
3108. The system ofclaim 3075, wherein the heated section of the formation is substantially pyrolyzed.
3109. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: a first conductor configurable to be disposed in a first conduit, wherein the first conduit is configurable to be disposed within an opening in the formation, and wherein the first conductor is further configurable to provide heat to at least a portion of the formation during use; and wherein the system is configurable to allow heat to transfer from the first conductor to a section of the foπnation during use.
3110. The system ofclaim 3109, wherein the first conductor is further configurable to generate heat during application of an electrical cunent to the first conductor.
3111. The system of claim 3109, wherein the first conductor comprises a pipe.
3112. The system ofclaim 3109, wherein the first conductor comprises stainless steel.
3113. The system of claim 3109, wherein the first conduit comprises stainless steel.
3114. The system of claim 3109, further comprising a cenfralizer configurable to maintain a location of the first conductor within the ffrst conduit.
3115. The system ofclaim 3109, further comprising a centtalizer configurable to maintain a location of the first conductor within the first conduit, wherein the centralizer comprises ceramic material.
3116. The system ofclaim 3109, further comprising a cenfralizer configurable to maintain a location of the first conductor within the first conduit, wherein the centralizer comprises ceramic material and stateless steel.
3117. The system of claim 3109, wherehi the opening comprises a diameter of at least approximately 5 cm.
3118. The system of claim 3109, further comprising a lead-in conductor coupled to the first conductor, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.
3119. The system of claim 3109, further comprising a lead-in conductor coupled to the first conductor, wherein the lead-in conductor comprises copper.
3120. The system ofclaim 3109, further comprising a sliding electrical connector coupled to the first conductor.
3121. The system of claim 3109, further comprising a sliding electrical connector coupled to the first conductor, wherein the sliding elecfrical connector is further coupled to the first conduit.
3122. The system of claim 3109, further comprising a sliding electrical connector coupled to the first conductor, wherein the sliding elecfrical connector is further coupled to the first conduit, and wherein the sliding electrical connector is configurable to complete an elecfrical circuit with the first conductor and the first conduit.
3123. The system of claim 3109, further comprising a second conductor disposed within the first conduit and at least one sliding elecfrical connector coupled to the first conductor and the second conductor, wherein at least the one sliding elecfrical connector is configurable to generate less heat than the first conductor or the second conductor during use.
3124. The system of claim 3109, wherein the first conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the ffrst conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.
3125. The system ofclaim 3109, further comprismg a fluid disposed within the first conduit, wherein the fluid is configurable to maintain a pressure within the first conduit to substantially inhibit deformation of the first conduit during use.
3126. The system ofclaim 3109, further comprising a thermally conductive fluid disposed within the first conduit.
3127. The system of claim 3109, further comprising a thennally conductive fluid disposed within the first conduit, wherein the thermally conductive fluid comprises helium.
3128. The system of claim 3109, further comprising a fluid disposed within the first conduit, wherein the fluid is configurable to substantially inhibit arcing between the first conductor and the first conduit during use.
3129. The system of claim 3109, further comprising a tube disposed within the opening external to the first conduit, wherein the tube is configurable to remove vapor produced from at least the heated portion of the foimation such that a pressure balance is maintained between the first conduit and the opening to substantially inhibit defoπnation of the first conduit during use.
3130. The system of claim 3109, wherein the first conductor is further configurable to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.
3131. The system of claim 3109, further comprising a second conductor disposed within a second conduit and a third conductor disposed within a thfrd conduit, wherein the first conduit, the second conduit and the third conduit are disposed in different openings of the formation, wherein the first conductor is elecfrically coupled to the second conductor and the third conductor, and wherein the first, second, and third conductors are configurable to operate in a 3-phase Y configuration during use.
3132. The system of claim 3109, further comprising a second conductor disposed within the first conduit, wherein the second conductor is elecfrically coupled to the first conductor to form an electrical circuit.
3133. The system of claim 3109, further comprising a second conductor disposed within the first conduit, wherein the second conductor is electrically coupled to the first conductor to form an elecfrical circuit with a connector.
3134. The system ofclaim 3109, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foimation.
3135. The system of claim 3109, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
3136. The system ofclaim 3109, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is fuither disposed in cement.
3137. The system ofclaim 3109, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherehi a packing material is disposed at a junction of the overburden casing and the opening.
3138.* The system of claim 3109, further comprising an overburden casing coupled to the openmg, wherein the overburden casing is disposed hi an overburden of the foπnation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
3139. The system of claim 3109, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to the first conductor.
3140. The system of claim 3109, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to the first conductor, and wherein the substantially low resistance conductor comprises carbon steel.
3141. The system ofclaim 3109, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing and a centtalizer configurable to support the substantially low resistance conductor within the overburden casing.
3142. The system of claim 3109, wherein the heated section of the formation is substantially pyrolyzed.
3143. The system ofclaim 3109, wherein the system is configured to heat a relatively low permeability foimation containing heavy hydrocarbons, and wherein the system comprises: a first conductor disposed in a first conduit, wherein the first conduit is disposed within an opening in the formation, and wherein the first conductor is configured to provide heat to at least a portion of the formation during use; and wherein the system is configured to allow heat to fransfer from the first conductor to a section of the formation during use.
3144. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising:
applying an electrical cunent to a first conductor to provide heat to at least a portion of the formation, wherein the first conductor is disposed in a first conduit, and wherein the first conduit is disposed withhi an opening in the formation; and allowing the heat to fransfer from the first conductor to a section of the fonnation.
3145. The method of claim 3144, wherein the first conductor comprises a pipe.
3146. The method of claim 3144, wherein the first conductor comprises stainless steel.
3147. The method ofclaim 3144, wherein the first conduit comprises stainless steel.
3148. The method of claim 3144, further comprising maintaining a location of the first conductor in the ffrst conduit with a cenfralizer.
3149. The method of claim 3144, further comprising maintaining a location of the first conductor in the first conduit with a cenfralizer, wherein the cenfralizer comprises ceramic material.
3150. The method ofclaim 3144, further comprising maintaining a location of the first conductor in the first conduit with a cenfralizer, wherein the centtalizer comprises ceramic material and stainless steel.
3151. The method of claim 3144, further comprising couplmg a sliding elecfrical connector to the first conductor.
3152. The method of claim 3144, further comprising elecfrically coupling a sliding elecfrical connector to the first conductor and the first conduit, wherein the first conduit comprises an elecfrical lead configured to complete an elecfrical circuit with the first conductor.
3153. The method of claim 3144, further comprising coupling a sliding elecfrical connector to the first conductor and the first conduit, wherein the first conduit comprises an electrical lead configured to complete an elecfrical circuit with the first conductor, and wherein the generated heat comprises approximately 20 percent generated by the first conduit.
3154. The method of claim 3144, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.
3155. The method of claim 3144, further comprising deteπnining a temperature distribution in the first conduit using an electromagnetic signal provided to the conduit.
3156. The method of claim 3144, further comprising monitoring the applied electrical cunent.
3157. The method of claim 3144, fuither comprising monitoring a voltage applied to the first conductor.
3158. The method of clahn 3144, further comprising monitoring a temperature in the conduit with at least one thermocouple.
3159. The method of claim 3144, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3160. The method of claim 3144, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed hi an overburden of the formation, and wherein the overburden casing comprises steel.
3161. The method of claim 3144, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the fonnation, and wherein the overburden casing is further disposed in cement.
3162. The method of claim 3144, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3163. The method ofclaim 3144, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.
3164. The method of claim 3144, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, and wherein the substantially low resistance conductor is electrically coupled to the first conductor.
3165. The method of claim 3144, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to the first conductor, and wherein the substantially low resistance conductor comprises carbon steel.
3166. The method of claim 3144, further comprishig coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, wherein the substantially low resistance conductor is electtically coupled to the first conductor, and wherein the method further comprises maintaining a location of the substantially low resistance conductor in the overburden casing with a centralizer support.
3167. The method ofclaim 3144, further comprismg electtically coupling a lead-in conductor to the first conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
3168. The method of claim 3144, further comprising elecfrically coupling a lead-in conductor to the first conductor, wherein the lead-in conductor comprises copper.
3169. The method of claim 3144, further comprising maintaining a sufficient pressure between the first conduit and the formation to substantially inhibit deformation of the first conduit.
3170. The method of claim 3144, fuither comprising providing a thennally conductive fluid within the first conduit.
3171. The method of claim 3144, further comprising providing a thermally conductive fluid within the first conduit, wherein the thermally conductive fluid comprises helium.
3172. The method ofclaim 3144, further comprising inhibiting arcing between the first conductor and the first conduit with a fluid disposed within the first conduit.
3173. The method ofclaim 3144, further comprising removing a vapor from the opening using a perforated tube disposed proximate to the first conduit in the openhig to control a pressure in the opening.
3174. The method of claim 3144, further comprising flowing a conosion inhibiting fluid through a perforated tube disposed proximate to the first conduit in the opening.
3175. The method ofclaim 3144, wherein a second conductor is disposed within the first conduit, wherein the second conductor is elecfrically coupled to the first conductor to form an elecfrical circuit.
3176. The method of claim 3144, wherein a second conductor is disposed within the first conduit, wherein the second conductor is electrically coupled to the first conductor with a connector.
3177. The method ofclaim 3144, wherein a second conductor is disposed within a second conduit and a third conductor is disposed within a third conduit, wherein the second conduit and the thfrd conduit are disposed in different openings of the formation, wherein the first conductor is electrically coupled to the second conductor and the third conductor, and wherein the first, second, and third conductors are configured to operate in a 3-phase Y configuration.
3178. The method of claim 3144, wherein a second conductor is disposed within the first conduit, wherein at least one sliding elecfrical connector is coupled to the first conductor and the second conductor, and wherein heat generated by at least the one sliding electrical connector is less than heat generated by the ffrst conductor or the second conductor.
3179. The method of claim 3144, wherein the first conduit comprises a first section and a second section, wherehi a thickness of the first section is greater than a thickness of the second section such that heat radiated from
the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.
3180. The method of clahn 3144, further comprising flowing an oxidizing fluid through an orifice in the first conduit.
3181. The method of claim 3144, further comprising disposing a perforated tube proximate to the first conduit and flowing an oxidizing fluid through the perforated tube.
3182. The method of claim 3144, fuither comprismg heating at least the portion of the foπnation to substantially pyrolyze at least some hydrocarbons within the formation.
3183. A system configured to heat a relatively low peπneability foπnation containing heavy hydrocarbons, comprising: a first conductor disposed in a first conduit, wherein the first conduit is disposed within a first opening in the formation; a second conductor disposed in a second conduit, wherein the second conduit is disposed within a second opening in the formation; a thfrd conductor disposed in a thfrd conduit, wherein the third conduit is disposed within a third opening in the formation, wherein the ffrst, second, and thfrd conductors are electrically coupled in a 3-phase Y configuration, and wherehi the first, second, and third conductors are configured to provide heat to at least a portion of the formation during use; and wherein the system is configured to allow heat to fransfer from the first, second, and third conductors to a selected section of the foπnation during use.
3184. The system of claim 3183, wherein the first, second, and third conductors are further configured to generate heat during application of an electrical cunent to the fh-st conductor.
3185. The system of claim 3183, wherein the first, second, and third conductors comprise a pipe.
3186. The system of claim 3183 , wherein the first, second, and third conductors comprise stainless steel.
3187. The system ofclaim 3183, wherein the first, second, and thfrd openings comprise a diameter of at least approximately 5 cm.
3188. The system of claim 3183, further comprishig a first sliding elecfrical connector coupled to the first conductor and a second sliding elecfrical connector coupled to the second conductor and a third sliding elecfrical connector coupled to the third conductor.
3189. The system of claim 3183, further comprising a first sliding electrical connector coupled to the first conductor, wherein the first sliding elecfrical connector is further coupled to the first conduit.
3190. The system ofclaim 3183, further comprising a second sliding elecfrical connector coupled to the second conductor, wherein the second sliding elecfrical connector is further coupled to the second conduit.
3191. The system ofclaim 3183, further comprising a third sliding elecfrical connector coupled to the third conductor, wherein the third sliding elecfrical connector is furtlier coupled to the third conduit.
3192. The system ofclaim 3183, wherein each of the first, second, and third conduits comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from each of the first, second, and third conductors to the section along the first section of each of the conduits is less than heat radiated from the first, second, and third conductors to the section along the second section of each of the conduits.
3193. The system ofclaim 3183, further comprising a fluid disposed within the first, second, and third conduits, wherein the fluid is configured to maintain a pressure within the first conduit to substantially inhibit deformation of the first, second, and third conduits during use.
3194. The system ofclaim 3183, further comprising a thermally conductive fluid disposed within the first, second, and third conduits.
3195. The system of claim 3183, further comprising a thermally conductive fluid disposed within the first, second, and thfrd conduits, wherein the thermally conductive fluid comprises helium.
3196. The system ofclaim 3183, further comprising a fluid disposed within the first, second, and third conduits, wherein the fluid is configured to substantiaUy inhibit arcing between the first, second, and third conductors and the first, second, and third conduits during use.
3197. The system ofclaim 3183, further comprising at least one tube disposed within the first, second, and third openings external to the first, second, and thfrd conduits, wherein at least the one tube is configured to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the first, second, and third conduits and the ffrst, second, and third openings to substantially inhibit deformation of the first, second, and third conduits during use.
3198. The system ofclaim 3183, wherein the first, second, and third conductors are further configured to generate radiant heat of approxhnately 650 W/m to approximately 1650 W/m during use.
3199. The system of claim 3183, furtlier comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation.
3200. The system ofclaim 3183, further comprising at least one overburden cashig coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein at least the one overburden casing comprises steel.
3201. The system of claim 3183 , further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the fonnation, and wherein at least the one overburden casing is further disposed in cement.
3202. The system ofclaim 3183, further comprising at least one overburden casing coupled to the first, second, and thfrd openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at ajunction of at least the one overburden casing and the first, second, and third openings.
3203. The system ofclaim 3183, further comprising at least one overburden casing coupled to the first, second, and thfrd openings, wherein at least the one overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at ajunction of at least the one overburden casing and the first, second, and thfrd openings, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the first, second, and third openings and at least the one overburden casing during use.
3204. The system of claim 3183, wherein the heated section of the foπnation is substantially pyrolyzed.
3205. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: a first conductor configurable to be disposed in a first conduit, wherein the first conduit is configurable to be disposed within a first opening in the formation; a second conductor configurable to be disposed in a second conduit, wherein the second conduit is configurable to be disposed within a second opening in the formation; a third conductor configurable to be disposed in a thfrd conduit, wherein the third conduit is configurable to be disposed within a third opening in the foπnation, wherein the first, second, and third conductors are further configurable to be elecfrically coupled in a 3-phase Y configuration, and wherein the first, second, and thfrd conductors are further configurable to provide heat to at least a portion of the formation during use; and wherein the system is configurable to allow heat to fransfer from the first, second, and third conductors to a selected section of the formation during use.
3206. The system ofclaim 3205, wherehi the first, second, and third conductors are further configurable to generate heat during application of an electrical cunent to the first conductor.
3207. The system ofclaim 3205, wherein the first, second, and third conductors comprise a pipe.
3208. The system of claim 3205, wherein the first, second, and third conductors comprise stainless steel.
3209. The system ofclaim 3205, wherein each of the first, second, and third openings comprises a diameter of at least approxhnately 5 cm.
3210. The system ofclaim 3205, further comprising a first sliding elecfrical connector coupled to the first conductor and a second sliding elecfrical connector coupled to the second conductor and a third sliding elecfrical connector coupled to the third conductor.
3211. The system ofclaim 3205, further comprising a first sliding electrical connector coupled to the first conductor, wherein the first sliding elecfrical connector is further coupled to the first conduit.
3212. The system ofclaim 3205, further comprising a second sliding electrical connector coupled to the second conductor, wherein the second sliding electrical connector is further coupled to the second conduit.
3213. The system of claim 3205, further comprising a third sliding elecfrical connector coupled to the third conductor, wherein the third sliding electrical connector is further coupled to the third conduit.
3214. The system of claim 3205, wherein each of the first, second, and thfrd conduits comprises a first section and a second section, wherehi a thickness of the ffrst section is greater than a thickness of the second section such that heat radiated from each of the first, second, and third conductors to the section along the first section of each of the conduits is less than heat radiated from the first, secondhand third conductors to the section along the second section of each of the conduits.
3215. The system of claim 3205, further comprising a fluid disposed within the first, second, and third conduits, wherein the fluid is configurable to maintain a pressure within the ffrst conduit to substantially inhibit deformation of the first, second, and third conduits during use.
3216. The system of claim 3205, further comprising a thermally conductive fluid disposed within the first, second, and third conduits.
3217. The system ofclaim 3205, further comprising a thermally conductive fluid disposed within the first, second, and third conduits, wherein the thermally conductive fluid comprises helium.
3218. The system of claim 3205, further comprising a fluid disposed withhi the first, second, and third conduits, wherein the fluid is configurable to substantially inhibit arcing between the first, second, and third conductors and the first, second, and third conduits during use.
3219. The system of claim 3205, further comprishig at least one tube disposed within the first, second, and third openings external to the first, second, and third conduits, wherein at least the one tube is configurable to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between
the first, second, and third conduits and the fnst, second, and thfrd openings to substantially inhibit deformation of the first, second, and third conduits during use.
3220. The system ofclaim 3205, wherein the first, second, and third conductors are further configurable to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.
3221. The system ofclaim 3205, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the fonnation.
3222. The system ofclaim 3205, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein at least the one overburden casing comprises steel.
3223. The system ofclaim 3205, furtlier comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein at least the one overburden casing is further disposed in cement.
3224. The system ofclaim 3205, further comprishig at least one overburden casing coupled to the ffrst, second, and thfrd openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at ajunction of at least the one overburden casing and the first, second, and third openings.
3225. The system ofclaim 3205, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden cashig is disposed in an overburden of the formation, wherein a packing material is disposed at ajunction of at least the one overburden casing and the first, second, and third openings, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the first, second, and thfrd openings and at least the one overburden casing during use.
3226. The system ofclaim 3205, wherein the heated section of the foπnation is substantially pyrolyzed.
3227. The system ofclaim 3205 wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a first conductor disposed in a first conduit, wherein the first conduit is disposed within a first opening in the foπnation; a second conductor disposed in a second conduit, wherein the second conduit is disposed within a second opening in the formation; a third conductor disposed in a third conduit, wherehi the third conduit is disposed within a thfrd opening in the formation, wherein the ffrst, second, and third conductors are electrically coupled in a 3-phase Y configuration, and wherein the ffrst, second, and third conductors are configured to provide heat to at least a portion of the formation during use; and
wherein the system is configured to allow heat to transfer from the first, second, and third conductors to a selected section of the formation during use.
3228. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprishig: applying an elecfrical cunent to a first conductor to provide heat to at least a portion of the formation, wherein the first conductor is disposed in a first conduit, and wherein the first conduit is disposed within a first opening in the foπnation; applying an elecfrical cunent to a second conductor to provide heat to at least a portion of the formation, wherein the second conductor is disposed in a second conduit, and wherehi the second conduit is disposed within a second opening in the formation; applying an electrical cunent to a thfrd conductor to provide heat to at least a portion of the foπnation, wherein the third conductor is disposed in a thfrd conduit, and wherein the third conduit is disposed within a third opening in the formation; and allowing the heat to fransfer from the first, second, and third conductors to a selected section of the formation.
3229. The method ofclaim 3228, wherein the ffrst, second, and thfrd conductors comprise a pipe.
3230. The method ofclaim 3228, wherein the ffrst, second, and third conductors comprise stainless steel.
3231. The method of claim 3228, wherein the first, second, and third conduits comprise stainless steel.
3232. The method of claim 3228, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.
3233. The method ofclaim 3228, further comprising determining a temperature distribution in the first, second, and third conduits using an electromagnetic signal provided to the first, second, and third conduits.
3234. The method of claim 3228, further comprising monitoring the applied electrical cunent.
3235. The method of claim 3228, further comprising monitoring a voltage applied to the first, second, and third conductors.
3236. The method of clahn 3228, further comprising monitoring a temperature in the first, second, and thfrd conduits with at least one thermocouple.
3237. The method of claim 3228, fuither comprising maintaining a sufficient pressure between the first, second, and third conduits and the first, second, and third openings to substantially inhibit deformation of the first, second, and third conduits.
3238. The method of clahn 3228, further comprising providing a thermally conductive fluid within the first, second, and third conduits.
3239. The method of clahn 3228, further comprising providing a thermally conductive fluid within the first, second, and third conduits, wherein the thermally conductive fluid comprises helium.
3240. The method ofclaim 3228, further comprising inhibiting arcing between the first, second, and third conductors and the first, second, and third conduits with a fluid disposed within the first, second, and thfrd conduits.
3241. The method of claim 3228, further comprising removing a vapor from the first, second, and third openings using at least one perforated tube disposed proxhnate to the first, second, and third conduits in the first, second, and third openings to control a pressure in the first, second, and third openings.
3242. The method ofclaim 3228, wherein the first, second, and third conduits comprise a first section and a second section, wherein a thickness of the fh-st section is greater than a thickness of the second section such that heat radiated from the first, second, and third conductors to the section along the first section of the ffrst, second, and thfrd conduits is less than heat radiated from the first, second, and thfrd conductors to the section along the second section of the first, second, and third conduits.
3243. The method of claim 3228, further comprising flowing an oxidizing fluid through an orifice in the first, second, and thfrd conduits.
3244. The method of claim 3228, further comprising heating at least the portion of the formation to substantially pyrolyze at least some hydrocarbons withhi the formation.
3245. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: a first conductor disposed in a conduit, wherein the conduit is disposed within an opening in the formation; and a second conductor disposed in the conduit, wherein the second conductor is electrically coupled to the first conductor with a connector, and wherein the first and second conductors are configured to provide heat to at least a portion of the formation during use; and wherein the system is configured to allow heat to transfer from the first and second conductors to a selected section of the formation during use.
3246. The system of claim 3245, wherein the first conductor is further configured to generate heat during application of an elecfrical cunent to the first conductor.
3247. The system ofclaim 3245, wherein the first and second conductors comprise a pipe.
3248. The system ofclaim 3245, wherein the first and second conductors comprise stainless steel.
3249. The system of clahn 3245, wherein the conduit comprises stainless steel.
3250. The system of claim 3245, further comprising a centralizer configured to maintain a location of the ffrst and second conductors within the conduit.
3251. The system of claim 3245, further comprising a cenfralizer configured to maintain a location of the first and second conductors within the conduit, wherein the cenfralizer comprises ceramic material.
3252. The system ofclaim 3245, further comprising a cenfralizer configured to maintain a location of the first and second conductors withhi the conduit, wherein the cenfralizer comprises ceramic material and stainless steel.
3253. The system of claim 3245, wherein the opening comprises a diameter of at least approximately 5 cm.
3254. The system of claim 3245, further comprising a lead-in conductor coupled to the ffrst and second conductors, wherehi the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
3255. The system ofclaim 3245, further comprising a lead-in conductor coupled to the first and second conductors, wherein the lead-in conductor comprises copper.
3256. The system ofclaim 3245, wherein the conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.
3257. The system ofclaim 3245, further comprising a fluid disposed within the conduit, wherein the fluid is configured to maintain a pressure within the conduit to substantially inhibit deformation of the conduit during use.
3258. The system of claim 3245, further comprising a thermally conductive fluid disposed within the conduit.
3259. The system ofclaim 3245, further comprising a thermally conductive fluid disposed within the conduit, wherein the thermally conductive fluid comprises helium.
3260. The system of claim 3245, further comprising a fluid disposed within the conduit, wherein the fluid is configured to substantially inhibit arcing between the first and second conductors and the conduit during use.
3261. The system of claim 3245, further comprising a tube disposed within the opening external to the conduit, wherein the tube is configured to remove vapor produced from at least the heated portion of the foπnation such that
a pressure balance is maintained between the conduit and the opening to substantially inhibit deformation of the conduit during use.
3262. The system of claim 3245, wherein the ffrst and second conductors are ftuther configured to generate radiant heat of approxhnately 650 W/m to approximately 1650 W/m during use.
3263. The system ofclaim 3245, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3264. The system ofclaim 3245, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
3265. The system ofclaim 3245, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing is further disposed in cement.
3266. The system ofclaim 3245, further comprising an overburden casing coupled to the openhig, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3267. The system ofclaim 3245, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
3268. The system of claim 3245, wherein the heated section of the formation is substantially pyrolyzed.
3269. A system configurable to heat a relatively low permeability fonnation containing heavy hydrocarbons, comprising: a first conductor configurable to be disposed in a conduit, wherein the conduit is configurable to be disposed within an opening in the formation; and a second conductor configurable to be disposed in the conduit, wherein the second conductor is configurable to be elecfrically coupled to the ffrst conductor with a connector, and wherein the first and second conductors are further configurable to provide heat to at least a portion of the foπnation during use; and wherein the system is configurable to allow heat to transfer from the first and second conductors to a selected section of the formation during use.
3270. The system ofclaim 3269, wherein the first conductor is further configurable to generate heat during application of an electrical cunent to the first conductor.
3271. The system of clahn 3269, wherein the ffrst and second conductors comprise a pipe.
3272. The system ofclaim 3269, wherein the first and second conductors comprise stainless steel.
3273. The system ofclaim 3269, whefein the conduit comprises stainless steel.
3274. The system ofclaim 3269, further comprising a cenfralizer configurable to maintain a location of the first and second conductors within the conduit.
3275. The system o claim 3269, further comprising a cenfralizer configurable to maintain a location of the first and second conductors within the conduit, wherein the cenfralizer comprises ceramic material.
3276. The "system ofclaim 3269, further comprising a centralizer configurable to maintain a location of the ffrst and second conductors within the conduit, wherein the centralizer comprises ceramic material and stainless steel.
3277. The system ofclaim 3269, wherein the opening comprises a diameter of at least approxhnately 5 cm.
3278. The system of clahn 3269, further comprising a lead-in conductor coupled to the first and second conductors, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.
3279. The system ofclaim 3269, further comprising a lead-in conductor coupled to the first and second conductors, wherein the lead-in conductor comprises copper.
3280. The system ofclaim 3269, wherein the conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.
3281. The system of claim 3269, further comprising a fluid disposed within the conduit, wherein the fluid is configurable to maintain a pressure within the conduit to substantially inhibit deformation of the conduit during use.
3282. The system of claim 3269, further comprising a thermally conductive fluid disposed within the conduit.
3283. The system of clahn 3269, further comprising a thermally conductive fluid disposed within the conduit, wherein the thermally conductive fluid comprises helium.
3284. The system of claim 3269, further comprising a fluid disposed within the conduit, wherein the fluid is configurable to substantially inhibit arcing between the first and second conductors and the conduit during use.
3285. The system ofclaim 3269, further comprising a tube disposed within the opening external to the conduit, wherein the tube is configurable to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the conduit and the opening to substantially inhibit defonnation of the conduit during use.
3286. The system ofclaim 3269, wherein the first and second conductors are further configurable to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.
3287. The system of claim 3269, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation.
3288. The system ofclaim 3269, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing comprises steel.
3289. The system of clahn 3269, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
3290. The system ofclaim 3269, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3291. The system of claim 3269, further comprising an overburden casing coupled to the openhig, wherein the overburden casing is disposed in an overburden of the formation, wherein a packhig material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
3292. The system of claim 3269, wherein the heated section of the foπnation is substantially pyrolyzed.
3293. The system ofclaim 3269, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a first conductor disposed in a conduit, wherein the conduit is disposed within an opening in the fonnation; a second conductor disposed in the conduit, wherein the second conductor is elecfrically coupled to the first conductor with a connector, and wherein the first and second conductors are configured to provide heat to at least a portion of the foπnation during use; and wherein the system is configured to allow heat to fransfer from the first and second conductors to a selected section of the formation during use.
3294. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: applying an electrical cunent to at least two conductors to provide heat to at least a portion of the formation, wherein at least the two conductors are disposed within a conduit, wherein the conduit is disposed within an opening in the formation, and wherein at least the two conductors are elecfrically coupled with a connector; and allowing heat to transfer from at least the two conductors to a selected section of the formation.
3295. The method of claim 3294, wherein at least the two conductors comprise a pipe.
3296. The method of claim 3294, wherein at least the two conductors comprise stainless steel.
3297. The method ofclaim 3294, wherein the conduit comprises stainless steel.
3298. The method ofclaim 3294, further comprishig maintaining a location of at least the two conductors in the conduit with a cenfralizer.
3299. The method ofclaim 3294, further comprising maintaining a location of at least the two conductors in the conduit with a cenfralizer, wherein the cenfralizer comprises ceramic material.
3300. The method ofclaim 3294, further comprising maintaining a location of at least the two conductors in the conduit with a cenfralizer, wherein the cenfralizer comprises ceramic material and stainless steel.
3301. The method of claim 3294, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.
3302. The method ofclaim 3294, further comprising determining a temperature distribution in the conduit using an electromagnetic signal provided to the conduit.
3303. The method of claim 3294, further comprising monitoring the applied electrical cunent.
3304. The method of clahn 3294, further comprising monitoring a voltage applied to at least the two conductors.
3305. The method ofclaim 3294, further comprising monitoring a temperature in the conduit with at least one thermocouple.
3306. The method of clahn 3294, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3307. The method of clahn 3294, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foimation, and wherein the overburden casing comprises steel.
3308. The method of claim 3294, further comprising coupling an overburden casing to the opening, wherein the overburden cashig is disposed in an overburden of the formation, and wherehi the overburden casing is further disposed in cement.
3309. The method ofclaim 3294, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3310. The method of claim 3294, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.
3 11. The method ofclaim 3294, further comprismg maintaining a sufficient pressure between the conduit and the formation to substantially inhibit defonnation of the conduit.
3312. The method of claim 3294, further comprismg providing a thermally conductive fluid within the conduit.
3313. The method ofclaim 3294, further comprising providing a thermally conductive fluid within the conduit, wherein the thermally conductive fluid comprises helium.
3314. The method of claim 3294, further comprising inhibiting arcing between at least the two conductors and the conduit with a fluid disposed within the conduit.
3315. The method ofclaim 3294, further comprising removing a vapor from the opening using a perforated tube disposed proximate to the conduit in the opening to confrol a pressure in the opening.
3316. The method ofclaim 3294, further comprising flowing a conosion inhibiting fluid through a perforated tube disposed proximate to the conduit in the opening.
3317. The method of clahn 3294, wherein the conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.
3318. The method of claim 3294, further comprising flowing an oxidizing fluid through an orifice in the conduit.
3319. The method of claim 3294, further comprising disposing a perforated tube proximate to the conduit and flowing an oxidizing fluid through the perforated tube.
3320. The method of claim 3294, further comprising heating at least the portion of the formation to substantially pyrolyze at least some hydrocarbons within the formation.
3321. A system configured to heat a relatively low permeability foπnation containing heavy hydrocarbons, comprising: at least one conductor disposed in a conduit, wherein the conduit is disposed within an opening in the formation, and wherein at least the one conductor is configured to provide heat to at least a first portion of the formation during use; at least one sliding connector, wherein at least the one sliding connector is coupled to at least the one conductor, wherein at least the one sliding connector is configured to provide heat during use, and wherein heat provided by at least the one sliding connector is substantiaUy less than the heat provided by at least the one conductor during use; and wherein the system is configured to allow heat to fransfer from at least the one conductor to a section of the formation during use.
3322. The system ofclaim 3321, wherein at least the one conductor is further configured to generate heat during application of an elecfrical cunent to at least the one conductor.
3323. The system ofclaim 3321, wherein at least the one conductor comprises a pipe.
3324. The system ofclaim 3321, wherein at least the one conductor comprises stainless steel.
3325. The system ofclaim 3321, wherein the conduit comprises stainless steel.
3326. The system ofclaim 3321, further comprising a cenfralizer configured to maintain a location of at least the one conductor within the conduit.
3327. The system ofclaim 3321, further comprising a centralizer configured to maintain a location of at least the one conductor within the conduit, wherein the centtalizer comprises ceramic material.
3328. The system of claim 3321 , further comprising a cenfralizer configured to maintain a location of at least the one conductor within the conduit, wherein the cenfralizer comprises ceramic material and stainless steel.
3329. The system of claim 3321, wherein the opening comprises a diameter of at least approxhnately 5 cm.
3330. The system ofclaim 3321, further comprising a lead-in conductor coupled to at least the one conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
3331. The system ofclaim 3321, further comprising a lead-in conductor coupled to at least the one conductor, wherein the lead-in conductor comprises copper.
3332. The system ofclaim 3321, wherein the conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the ffrst conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.
3333. The system ofclaim 3321, further comprising a fluid disposed within the conduit, wherein the fluid is configured to maintain a pressure within the conduit to substantially inhibit deformation of the conduit during use.
3334. The system ofclaim 3321, further comprising a thennally conductive fluid disposed within the conduit.
3335. The system ofclaim 3321, further comprising a thermally conductive fluid disposed within the conduit, wherein the thermally conductive fluid comprises helium.
3336. The system of clahn 3321, further comprising a fluid disposed within the conduit, wherein the fluid is configured to substantially inhibit arcing between at least the one conductor and the conduit during use.
3337. The system ofclaim 3321, further comprising a tube disposed within the opening external to the conduit, wherein the tube is configured to remove vapor produced from at least the heated portion of the foimation such that a pressure balance is maintained between the conduit and the opening to substantially inhibit deformation of the conduit during use.
3338. The system ofclaim 3321, wherein at least the one conductor is further configured to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.
3339. The system ofclaim 3321, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3340. The system ofclaim 3321, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
3341. The system ofclaim 3321, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherehi the overburden casing is further disposed in cement.
3342. The system ofclaim 3321, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3343. The system of claim 3321, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
3344. The system ofclaim 3321, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to at least the one conductor.
3345. The system o claim 3321, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is elecfrically coupled to at least the one conductor, and wherein the substantially low resistance conductor comprises carbon steel.
3346. The system ofclaim 3321, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing and a cenfralizer configured to support the substantially low resistance conductor within the overburden casing.
3347. The system ofclaim 3321, wherein the heated section of the formation is substantially pyrolyzed.
3348. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: at least one conductor configurable to be disposed in a conduit, wherein the conduit is configurable to be disposed within an opening in the formation, and wherein at least the one conductor is further configurable to provide heat to at least a first portion of the formation during use; at least one sliding connector, wherein at least the one sliding connector is configurable to be coupled to at least the one conductor, wherein at least the one sliding connector is further configurable to provide heat during use, and wherein heat provided by at least the one sliding connector is substantially less than the heat provided by at least the one conductor during use; and wherein the system is configurable to allow heat to transfer from at least the one conductor to a section of the formation during use.
3349. The system of claim 3348, wherein at least the one conductor is further configurable to generate heat durmg application of an electrical cunent to at least the one conductor.
3350. The system ofclaim 3348, wherein at least the one conductor comprises a pipe.
3351. The system of clahn 3348, wherein at least the one conductor comprises stainless steel.
3352. The system ofclaim 3348, wherehi the conduit comprises stainless steel.
3353. The system ofclaim 3348, further comprising a cenfralizer configurable to maintain a location of at least the one conductor within the conduit.
3354. The system ofclaim 3348, further comprising a centralizer configurable to maintain a location of at least the one conductor within the conduit, wherein the cenfralizer comprises ceramic material.
3355. The system ofclaim 3348, further comprising a cenfralizer configurable to maintain a location of at least the one conductor within the conduit, wherein the cenfralizer comprises ceramic material and stainless steel.
3356. The system ofclaim 3348, wherein the opening comprises a diameter of at least approximately 5 cm.
3357. The system of claim 3348, further comprising a lead-in conductor coupled to at least the one conductor, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.
3358. The system of clahn 3348, further comprising a lead-in conductor coupled to at least the one conductor, wherein the lead-in conductor comprises copper.
3359. The system ofclaim 3348, wherein the conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.
3360. The system of claim 3348, further comprising a fluid disposed within the conduit, wherein the fluid is configurable to maintain a pressure within the conduit to substantially inhibit deformation of the conduit during use.
3361. The system of clahn 3348, further comprising a thermally conductive fluid disposed within the conduit.
3362. The system of claim 3348, further comprising a thermally conductive fluid disposed withhi the conduit, wherein the thermally conductive fluid comprises helium.
3363. The system ofclaim 3348, further comprising a fluid disposed withhi the conduit, wherein the fluid is configurable to substantially inhibit arcing between at least the one conductor and the conduit during use.
3364. The system of claim 3348, further comprising a tube disposed within the opening external to the conduit, wherein the tube is configurable to remove vapor produced from at least the heated portion of the foimation such
that a pressure balance is maintained between the conduit and the opening to substantially inhibit deformation of the conduit during use.
3365. The system of clahn 3348, wherein at least the one conductor is further configurable to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.
3366. The system ofclaim 3348, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3367. The system ofclaim 3348, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing comprises steel.
3368. The system ofclaim 3348, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing is further disposed in cement.
3369. The system of claim 3348, further comprising an overburden casing coupled to the opening, wherehi the overburden casing is disposed in an overburden of the foπnation, and wherein a packing material is disposed at a junction of the overburden casing and the openhig.
3370. The system of claim 3348, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
3371. The system ofclaim 3348, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to at least the one conductor.
3372. The system ofclaim 3348, further comprismg an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is elecfrically coupled to at least the one conductor, and wherein the substantially low resistance conductor comprises carbon steel.
3373. The system o claim 3348, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing and a cenfralizer configurable to • support the substantially low resistance conductor within the overburden casing.
3374. The system ofclaim 3348, wherein the heated section of the formation is substantially pyrolyzed.
3375. The system of claim 3348, wherein the system is configured to heat a relatively low permeability foπnation containing heavy hydrocarbons, and wherein the system comprises: at least one conductor disposed in a conduit, wherein the conduit is disposed within an opening in the formation, and wherein at least the one conductor is configured to provide heat to at least a first portion of the formation during use; at least one sliding connector, wherein at least the one sliding connector is coupled to at least the one conductor, wherein at least the one sliding connector is configured to provide heat during use, and wherein heat provided by at least the one sliding connector is substantially less than the heat provided by at least the one conductor during use; and wherein the system is configured to allow heat to fransfer from at least the one conductor to a section of the formation during use.
3376. An in situ method for heating a relatively low peπneability formation containing heavy hydrocarbons, comprising: applying an elecfrical cunent to at least one conductor and at least one sliding connector to provide heat to at least a portion of the formation, wherein at least the one conductor and at least the one sliding connector are disposed within a conduit, and wherein heat provided by at least the one conductor is substantially greater than heat provided by at least the one sliding connector; and allowing the heat to transfer from at least the one conductor and at least the one sliding connector to a section of the foπnation.
3377. The method ofclaim 3376, wherein at least the one conductor comprises a pipe.
3378. The method ofclaim 3376, wherein at least the one conductor comprises stainless steel.
3379. The method of claim 3376, wherein the conduit comprises stainless steel.
3380. The method of claim 3376, further comprising maintaining a location of at least the one conductor in the conduit with a centtalizer.
3381. The method of claim 3376, further comprising maintaining a location of at least the one conductor in the conduit with a centtalizer, wherein the cenfralizer comprises ceramic material.
3382. The method of claim 3376, further comprising maintaining a location of at least the one conductor in the conduit with a centralizer, wherein the centralizer comprises ceramic material and stainless steel.
3383. The method ofclaim 3376, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.
3384. The method of clahn 3376, further comprishig determining a temperature disfribution in the conduit using an electromagnetic signal provided to the conduit.
3385. The method ofclaim 3376, further comprising monitoring the applied elecfrical cunent.
3386. The method ofclaim 3376, further comprising monitoring a voltage applied to at least the one conductor.
3387. The method ofclaim 3376, further comprising monitoring a temperature in the conduit with at least one thermocouple.
3388. The method ofclaim 3376, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the fonnation.
3389. The method ofclaim 3376, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the fonnation, and wherein the overburden casing comprises steel.
3390. The method ofclaim 3376, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
3391. The method of claim 3376, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherehi a packing material is disposed at a junction of the overburden casing and the opening.
3392. The method ofclaim 3376, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.
3393. The method of claim 3376, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, and wherein the substantially low resistance conductor is electtically coupled to at least the one conductor.
3394. The method of clahn 3376, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, wherein the substantially low resistance conductor is electtically coupled to at least the one conductor, and wherein the substantially low resistance conductor comprises carbon steel.
3395. The method ofclaim 3376, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, wherein the substantially low
resistance conductor is electtically coupled to at least the one conductor, and wherein the method further comprises maintaining a location of the substantially low resistance conductor in the overburden casing with a centtalizer support.
3396. The method of clahn 3376, further comprising electrically coupling a lead-in conductor to at least the one conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
3397. The method ofclaim 3376, further comprising electtically coupling a lead-in conductor to at least the one conductor, wherein the lead-in conductor comprises copper.
3398. The method ofclaim 3376, further comprising maintaining a sufficient pressure between the conduit and the foimation to substantially inhibit defonnation of the conduit.
3399. The method ofclaim 3376, further comprising providing a thermally conductive fluid within the conduit.
3400. The method of claim 3376, further comprising providing a thermally conductive fluid within the conduit, wherein the thermally conductive fluid comprises helium.
3401. The method ofclaim 3376, further comprising inhibiting arcing between the conductor and the conduit with a fluid disposed within the conduit.
3402. The method of claim 3376, further comprising removing a vapor from the opening using a perforated tube disposed proximate to the conduit in the opening to control a pressure in the openhig.
3403. The method ofclaim 3376, further comprising flowing a conosion inhibiting fluid through a perforated tube disposed proxhnate to the conduit in the opening.
3404. The method ofclaim 3376, further comprising flowing an oxidizing fluid through an orifice in the conduit.
3405. The method ofclaim 3376, further comprising disposing a perforated tube proximate to the conduit and flowing an oxidizing fluid through the perforated tube.
3406. The method of clahn 3376, further comprising heating at least the portion of the formation to substantially pyrolyze at least some hydrocarbons withhi the foπnation.
3407. A system configured to heat a relatively low peπneability formation containing heavy hydrocarbons, comprising: at least one elongated member disposed within an opening in the formation, wherein at least the one elongated member is configured to provide heat to at least a portion of the formation during use; and
wherein the system is configured to allow heat to ttansfer from at least the one elongated member to a section of the formation during use.
3408. The system of claim 3407, wherein at least the one elongated member comprises stainless steel.
3409. The system of claim 3407, wherein at least the one elongated member is further configured to generate heat during application of an electrical cunent to at least the one elongated member.
3410. The system ofclaim 3407, further comprising a support member coupled to at least the one elongated member, wherein the support member is configured to support at least the one elongated member.
3411. The system of claim 3407, furtlier comprising a support member coupled to at least the one elongated member, wherein the support member is configured to support at least the one elongated member, and wherein the support member comprises openings.
3412. The system of claim 3407, further comprising a support member coupled to at least the one elongated member, wherein the support member is configured to support at least the one elongated member, wherein the support member comprises openings, wherein the openings are configured to flow a fluid along a length of at least the one elongated member during use, and wherein the fluid is configured to substantially inhibit carbon deposition on or proxhnate to at least the one elongated member during use.
3413. The system of clahn 3407, further comprismg a tube disposed in the opening, wherein the tube comprises openings, wherein the openings are configured to flow a fluid along a length of at least the one elongated member during use, and wherein the fluid is configured to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use.
3414. The system ofclaim 3407, further comprising a centtalizer coupled to at least the one elongated member, wherein the centralizer is configured to electrically isolate at least die one elongated member.
3415. The system ofclaim 3407, further comprising a cenfralizer coupled to at least the one elongated member and a support member coupled to at least the one elongated member, wherein the cenfralizer is configured to maintain a location of at least the one elongated member on the support member.
3416. The system ofclaim 3407, wherein the opening comprises a diameter of at least approxhnately 5 cm.
3417. The system ofclaim 3407, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
3418. The system ofclaim 3407, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a rubber insulated conductor.
3419. The system ofclaim 3407, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises copper wire.
3420. The system ofclaim 3407, further comprising a lead-in conductor coupled to at least the one elongated member with a cold phi fransition conductor.
3421. The system ofclaim 3407, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin fransition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.
3422. The system ofclaim 3407, wherein at least the one elongated member is ananged in a series electrical configuration.
3423. The system ofclaim 3407, wherein at least the one elongated member is ananged in a parallel elecfrical configuration.
3424. The system of claim 3407, wherein at least the one elongated member is configured to generate radiant heat of approxhnately 650 W/m to approximately 1650 W/m during use.
3425. The system of claim 3407, further comprising a perforated tube disposed in the opening external to at least the one elongated member, wherein the perforated tube is configured to remove vapor from the opening to control a pressure in the opening during use.
3426. The system ofclaim 3407, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3427. The system of claim 3407, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing comprises steel.
3428. The system ofclaim 3407, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
3429. The system of claim 3407, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3430. The system ofclaim 3407, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
3431. The system ofclaim 3407, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherehi the packing material is further configured to substantially mhibit a flow of fluid between the opening and the overburden casing during use.
3432. The system ofclaim 3407, wherein the heated section of the formation is substantially pyrolyzed.
3433. A system configurable to heat a relatively low peπneability foπnation containing heavy hydrocarbons, comprising: at least one elongated member configurable to be disposed within an opening in the fonnation, wherein at least the one elongated member is further configurable to provide heat to at least a portion of the formation during use; and wherein the system is configurable to allow heat to transfer from at least the one elongated member to a section of the formation during use.
3434. The system of claim 3433, wherein at least the one elongated member comprises stainless steel.
3435. The system ofclaim 3433, wherein at least the one elongated member is further configurable to generate heat during application of an electrical cunent to at least the one elongated member.
3436. The system ofclaim 3433, further comprising a support member coupled to at least the one elongated member, wherein the support member is configurable to support at least the one elongated member.
3437. The system ofclaim 3433, further comprising a support member coupled to at least the one elongated member, wherein the support member is configurable to support at least the one elongated member, and wherein the support member comprises openings.
3438. The system ofclaim 3433, further comprising a support member coupled to at least the one elongated member, wherehi the support member is configurable to support at least the one elongated member, wherein the support member comprises openings, wherein the openings are configurable to flow a fluid along a length of at least the one elongated member durmg use, and wherein the fluid is configurable to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use.
3439. The system ofclaim 3433, further comprising a tube disposed in the opening, wherein the tube comprises openmgs, wherein the openings are configurable to flow a fluid along a length of at least the one elongated member
during use, and wherein the fluid is configurable to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use.
3440. The system ofclaim 3433, further comprising a cenfralizer coupled to at least the one elongated member, wherein the centralizer is configurable to electrically isolate at least the one elongated member.
3441. The system ofclaim 3433, further comprising a centralizer coupled to at least the one elongated member and a support member coupled to at least the one elongated member, wherein the centralizer is configurable to maintain a location of at least the one elongated member on the support member.
3442. The system ofclaim 3433, wherein the opening comprises a diameter of at least approximately 5 cm.
3443. The system ofclaim 3433, furtlier comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.
3444. The system ofclaim 3433, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a rubber insulated conductor.
3445. The system ofclaim 3433, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises copper wire.
3446. The system ofclaim 3433, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor.
3447. The system ofclaim 3433, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.
3448. The system of claim 3433, wherein at least the one elongated member is ananged in a series electrical configuration.
3449. The system ofclaim 3433, wherein at least the one elongated member is ananged in a parallel elecfrical configuration.
3450. The system of clahn 3433, wherein at least the one elongated member is configurable to generate radiant heat of approxhnately 650 W/m to approximately 1650 W/m during use.
3451. The system of claim 3433, further comprishig a perforated tube disposed in the opening external to at least the one elongated member, wherein the perforated tube is configurable to remove vapor from the opening to control a pressure in the opening during use.
3452. The system ofclaim 3433, further comprising an overburden casing coupled to the openhig, wherein the overburden casing is disposed in an overburden of the formation.
3453. The system ofclaim 3433, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
3454. The system ofclaim 3433, further comprising an overburden casing coupled to the openmg, wherein the overburden casing is disposed in an overburden of the fonnation, and wherein the overburden casing is further disposed in cement.
3455. The system ofclaim 3433, furtlier comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3456. The system ofclaim 3433, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foimation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
3457. The system ofclaim 3433, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
3458. The system ofclaim 3433, wherein the heated section of the formation is substantially pyrolyzed.
3459. The system of claim 3433, wherein the system is configured to heat a relatively low permeability foπnation containing heavy hydrocarbons, and wherein the system comprises: at least one elongated member disposed within an opening in the formation, wherein at least the one elongated member is configured to provide heat to at least a portion of the foπnation during use; and wherein the system is configured to allow heat to fransfer from at least the one elongated member to a section of the formation during use.
3460. An in situ method for heating a relatively low peπneability formation containing heavy hydrocarbons, comprising:
applying an electrical cunent to at least one elongated member to provide heat to at least a portion of the formation, wherein at least the one elongated member is disposed within an opening of the foπnation; and allowing heat to fransfer from at least the one elongated member to a section of the fonnation.
3461. The method ofclaim 3458, wherein at least the one elongated member comprises a metal strip.
3462. The method ofclaim 3458, wherein at least the one elongated member comprises a metal rod.
3463. The method ofclaim 3458, wherein at least the one elongated member comprises stainless steel.
3464. The method of claim 3458, further comprising supporting at least the one elongated member on a center support member.
3465. The method ofclaim 3458, further comprising supporting at least the one elongated member on a center support member, wherein the center support member comprises a tube.
3466. The method ofclaim 3458, further comprising elecfrically isolating at least the one elongated member with a centralizer.
3467. The method of claim 3458, further comprising laterally spacing at least the one elongated member with a centtalizer.
3468. The method of claim 3458, further comprising elecfrically coupling at least the one elongated member in a series configuration.
3469. The method of claim 3458, further comprising elecfrically coupling at least the one elongated member in a parallel configuration.
3470. The method ofclaim 3458, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.
3471. The method of claim 3458, further comprising determining a temperature disfribution in at least the one elongated member using an electromagnetic signal provided to at least the one elongated member.
3472. The method of clahn 3458, further comprising monitoring the applied elecfrical cunent.
3473. The method of claim 3458, further comprising monitoring a voltage applied to at least the one elongated member.
3474. The method ofclaim 3458, further comprising monitoring a temperature in at least the one elongated member with at least one thermocouple.
3475. The method ofclaim 3458, further comprising supporting at least the one elongated member on a center support member, wherein the center support member comprises openings, the method further comprising flowing an oxidizing fluid through the openings to substantially inhibit carbon deposition proximate to or on at least the one elongated member.
3476. The method of claim 3458, further comprising flowing an oxidizing fluid through a tube disposed proximate to at least the one elongated member to substantially inhibit carbon deposition proximate to or on at least the one elongated member.
3477. The method ofclaim 3458, further comprising flowing an oxidizing fluid through an opening in at least the one elongated member to substantially inhibit carbon deposition proximate to or on at least the one elongated member.
3478. The method ofclaim 3458, further comprising electrically coupling a lead-in conductor to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.
3479. The method of clahn 3458, further comprising elecfrically coupling a lead-in conductor to at least the one elongated member using a cold pin fransition conductor.
3480. The method of claim 3458, further comprising elecfrically coupling a lead-in conductor to at least the one elongated member using a cold pin fransition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.
3481. The method of claim 3458, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3482. The method of claim 3458, further comprising coupling an overburden casing to the opening, wherein the overburden casing comprises steel.
3483. The method of clahn 3458, further comprising coupling an overburden cashig to the opening, wherein the overburden casing is disposed in cement.
3484. The method of clahn 3458, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
3485. The method of clahn 3458, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with the packing material.
3486. The method ofclaim 3458, further comprising heating at least the portion of the formation to substantially pyrolyze at least some hydrocarbons within the foπnation.
3487. A system configured to heat a relatively low permeability foπnation containing heavy hydrocarbons, comprising: at least one elongated member disposed within an opening in the foπnation, wherein at least the one elongated member is configured to provide heat to at least a portion of the formation during use; an oxidizing fluid source; a conduit disposed within the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to the opening during use, and wherein the oxidizing fluid is selected to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use; and wherein the system is configured to allow heat to fransfer from at least the one elongated member to a section of the formation during use.
3488. The system ofclaim 3487, wherein at least the one elongated member comprises stainless steel.
3489. The system ofclaim 3487, wherein at least the one elongated member is further configured to generate heat during application of an elecfrical cunent to at least the one elongated member.
3490. The system ofclaim 3487, wherein at least the one elongated member is coupled to the conduit, wherein the conduit is further configured to support at least the one elongated member.
3491. The system ofclaim 3487, wherein at least the one elongated member is coupled to the conduit, wherein the conduit is further configured to support at least the one elongated member, and wherein the conduit comprises openings.
3492. The system ofclaim 3487, further comprising a cenfralizer coupled to at least the one elongated member and the conduit, wherein the cenfralizer is configured to electrically isolate at least the one elongated member from the conduit.
3493. The system of clahn 3487, further comprishig a centralizer coupled to at least the one elongated member and the conduit, wherein the centtalizer is configured to maintain a location of at least the one elongated member on the conduit.
3494. The system of claim 3487, wherein the opening comprises a diameter of at least approximately 5 cm.
3495. The system ofclaim 3487, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-hi conductor comprises a low resistance conductor configured to generate substantially no heat.
3496. The system of clahn 3487, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a rubber insulated conductor.
3497. The system ofclaim 3487, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises copper wire.
3498. The system ofclaim 3487, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin fransition conductor.
3499. The system ofclaim 3487, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor, wherein the cold pin fransition conductor comprises a substantially low resistance insulated conductor.
3500. The system ofclaim 3487, wherein at least the one elongated member is ananged in a series elecfrical configuration.
3501. The system of claim 3487, wherein at least the one elongated member is ananged in a parallel electrical configuration.
3502. The system ofclaim 3487, wherein at least the one elongated member is configured to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.
3503. The system ofclaim 3487, further comprising a perforated tube disposed in the opening external to at least the one elongated member, wherein the perforated tube is configured to remove vapor from the opening to confrol a pressure in the opening during use.
3504. The system ofclaim 3487, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3505. The system ofclaim 3487, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
3506. The system of claim 3487, further comprising an overburden casing coupled to the opening, wherehi the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
3507. The system ofclaim 3487, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packhig material is disposed at a junction of the overburden casing and the opening.
3508. The system of clahn 3487, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.
3509. The system ofclaim 3487, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the openhig and the overburden casing during use.
3510. The system ofclaim 3487, wherein the heated section of the formation is substantially pyrolyzed.
3511. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: at least one elongated member configurable to be disposed within an opening in the fonnation, wherein at least the one elongated member is further configurable to provide heat to at least a portion of the formation during use; a conduit configurable to be disposed within the opening, wherehi the conduit is further configurable to provide an oxidizing fluid from the oxidizing fluid source to the opening during use, and wherein the system is configurable to allow the oxidizing fluid to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use; and wherein the system is further configurable to allow heat to transfer from at least the one elongated member to a section of the formation during use.
3512. The system ofclaim 3511, wherehi at least the one elongated member comprises stainless steel.
3513. The system ofclaim 3511, wherein at least the one elongated member is further configurable to generate heat during application of an electrical cunent to at least the one elongated member.
3514. The system ofclaim 3511, wherehi at least the one elongated member is coupled to the conduit, wherein the conduit is further configurable to support at least the one elongated member.
3515. The system ofclaim 3511, wherein at least the one elongated member is coupled to the conduit, wherein the conduit is further configurable to support at least the one elongated member, and wherein the conduit comprises openings.
3516. The system ofclaim 3511, further comprising a centralizer coupled to at least the one elongated member and the conduit, wherein the centralizer is configurable to electrically isolate at least the one elongated member from the conduit.
3517. The system of claim 3511, further comprising a centralizer coupled to at least the one elongated member and the conduit, wherem the centtalizer is configurable to maintain a location of at least the one elongated member on the conduit.
3518. The system ofclaim 3511, wherein the opening comprises a diameter of at least approximately 5 cm.
3519. The system of claim 3511, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.
3520. The system of claim 3511, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a rubber insulated conductor.
3521. The system of claim 3511, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises copper wire.
3522. The system ofclaim 3511, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin fransition conductor.
3523. The system ofclaim 3511, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.
3524. The system ofclaim 3511, wherein at least the one elongated member is ananged in a series elecfrical configuration.
3525. The system ofclaim 3511, wherein at least the one elongated member is ananged in a parallel elecfrical configuration.
3526. The system ofclaim 3511, wherein at least the one elongated member is configurable to generate radiant heat' of approximately 650 W/m to approximately 1650 W/m during use.
3527. The system of claim 3511, further comprising a perforated tube disposed in the opening external to at least the one elongated member, wherein the perforated tube is configurable to remove vapor from the opening to confrol a pressure in the openmg during use.
3528. The system of claim 3511, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3529. The system of clahn 3511, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein the overburden casing comprises steel.
3530. The system ofclaim 3511, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
3531. The system ofclaim 3511, furtlier comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the foπnation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.
3532. The system ofclaim 3511, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the openhig, and wherein the packing material comprises cement.
3533. The system ofclaim 3511, further comprising an overburden casing coupled to the opening, wherehi the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.
3534. The system of claim 3511, wherein the heated section of the formation is substantially pyrolyzed.
3535. The system ofclaim 3511, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: at least one elongated member disposed within an opening in the formation, wherein at least the one elongated member is configured to provide heat to at least a portion of the fonnation during use; an oxidizing fluid source; a conduit disposed within the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to the opening during use, and wherein the oxidizing fluid is selected to substantially inhibit carbon deposition on or proxhnate to at least the one elongated member during use; and wherein the system is configured to allow heat to transfer from at least the one elongated member to a section of the fonnation during use.
3536. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising:
applying an elecfrical cunent to at least one elongated member to provide heat to at least a portion of the formation, wherein at least the one elongated member is disposed within an opening in the formation; providing an oxidizing fluid to at least the one elongated member to substantially inhibit carbon deposition on or proximate to at least the one elongated member; and allowing heat to transfer from at least the one elongated member to a section of the foπnation.
3537. The method ofclaim 3536, wherein at least the one elongated member comprises a metal strip.
3538. The method ofclaim 3536, wherein at least the one elongated member comprises a metal rod.
3539. The method ofclaim 3536, wherein at least the one elongated member comprises stainless steel.
3540. The method ofclaim 3536, further comprising supporting at least the one elongated member on a center support member.
3541. The method of claim 3536, further comprising supporting at least the one elongated member on a center support member, wherein the center support member comprises a tube.
3542. The method ofclaim 3536, further comprising elecfrically isolating at least the one elongated member with a centtalizer.
3543. The method of claim 3536, further comprising laterally spacing at least the one elongated member with a cenfralizer.
3544. The method of claim 3536, further comprising electtically coupling at least the one elongated member in a series configuration.
3545. The method of claim 3536, further comprising electrically coupling at least the one elongated member in a parallel configuration.
3546. The method of clahn 3536, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.
3547. The method of clahn 3536, further comprising deteπnining a temperature distribution in at least the one elongated member using an electromagnetic signal provided to at least the one elongated member.
3548. The method of clahn 3536, further comprising monitoring the applied electrical cunent.
3549. The method ofclaim 3536, further comprising monitoring a voltage applied to at least the one elongated member.
3550. The method ofclaim 3536, further comprising monitoring a temperature in at least the one elongated member with at least one thermocouple.
3551. The method of clahn 3536, further comprising supporting at least the one elongated member on a center support member, wherein the center support member comprises openings, wherein providing the oxidizing fluid to at least the one elongated member comprises flowing the oxidizing fluid through the openings in the center support member.
3552. The method ofclaim 3536, wherein providing the oxidizing fluid to at least the one elongated member comprises flowing the oxidizing fluid through orifices in a tube disposed in the opening proximate to at least the one elongated member.
3553. The method ofclaim 3536, further comprising elecfrically coupling a lead-in conductor to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantiaUy no heat.
3554. The method ofclaim 3536, further comprising electrically coupling a lead-in conductor to at least the one elongated member using a cold pin transition conductor.
3555. The method ofclaim 3536, further comprising electrically coupling a lead-in conductor to at least the one elongated member using a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.
3556. The method of claim 3536, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.
3557. The method ofclaim 3536, further comprising coupling an overburden casing to the opening, wherein the overburden casing comprises steel.
3558. The method of claim 3536, further comprising couplhig an overburden casing to the opening, wherein the overburden cashig is disposed in cement.
3559. The method ofclaim 3536, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening.
3560. The method of clahn 3536, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at ajunction of the overburden casing and the opening, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with the packing material.
3561. The method ofclaim 3536, further comprising heating at least the portion of the formation to substantially pyrolyze at least some hydrocarbons within the formation.
3562. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: oxidizing a fuel fluid in a heater; providing at least a portion of the oxidized fuel fluid into a conduit disposed in an opening of the formation; allowing heat to ttansfer from the oxidized fuel fluid to a section of the formation; and allowing additional heat to transfer from an elecfric heater disposed in the opening to the section of the formation, wherein heat is allowed to fransfer substantially uniformly along a length of the opening.
3563. The method ofclaim 3562, wherein providing at least the portion of the oxidized fuel fluid into the opening comprises flowing the oxidized fuel fluid through a perforated conduit disposed in the opening.
3564. The method ofclaim 3562, wherein providing at least the portion of the oxidized fuel fluid into the opening comprises flowing the oxidized fuel fluid through a perforated conduit disposed in the opening, the method further comprising removing an exhaust fluid through the opening.
3565. The method ofclaim 3562, further comprising initiating oxidation of the fuel fluid in the heater with a flame.
3566. The method ofclaim 3562, further comprising removing the oxidized fuel fluid through the conduit.
3567. The method of claim 3562, further comprising removing the oxidized fuel fluid through the conduit and providing the removed oxidized fuel fluid to at least one additional heater disposed in the foπnation.
3568. The method of claim 3562, wherein the conduit comprises an insulator disposed on a surface of the conduit, the method further comprising tapering a thickness of the insulator such that heat is allowed to fransfer substantially uniformly along a length of the conduit.
3569. The method ofclaim 3562, wherein the elecfric heater is an insulated conductor.
3570. The method ofclaim 3562, wherein the electric heater is a conductor disposed in the conduit.
3571. The method ofclaim 3562, wherein the electric heater is an elongated conductive member.
3572. A system configured to heat a relatively low permeability formation containing heavy hydrocarbons, comprising:
one or more heat sources disposed within one or more open wellbores in the formation, wherehi the one or more heat sources are configured to provide heat to at least a portion of the formation during use; and wherein the system is configured to allow heat to fransfer from the one or more heat sources to a selected section of the formation during use.
3573. The system ofclaim 3572, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
3574. The system of claim 3572, wherein the one or more heat sources comprise elecfrical heaters.
3575. The system ofclaim 3572, wherein the one or more heat sources comprise surface burners.
3576. The system ofclaim 3572, wherein the one or more heat sources comprise flameless distributed combustors.
3577. The system ofclaim 3572, wherein the one or more heat sources comprise natural disfributed combustors.
3578. The system ofclaim 3572, wherein the one or more open wellbores comprise a diameter of at least approximately 5 cm.
3579. The system ofclaim 3572, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation.
3580. The system ofclaim 3572, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.
3581. The system ofclaim 3572, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden cashig is disposed in an overburden of the formation, and wherein the overburden casing is fuither disposed in cement.
3582. The system ofclaim 3572, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at ajunction of the overburden cashig and the at least one of the one or more open wellbores.
3583. The system ofclaim 3572, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, wherein a packhig material is disposed at ajunction of the overburden casing and the at least one of the one or more open
wellbores, and wherein the packing material is configured to substantially inhibit a flow of fluid between at least one of the one or more open wellbores and the overburden casing during use.
3584. The system ofclaim 3572, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at ajunction of the overburden casing and the at least one of the one or more open wellbores, and wherein the packing material comprises cement.
3585. The system ofclaim 3572, wherein the system is further configured to fransfer heat such that the fransfened heat can pyrolyze at least some hydrocarbons in the selected section.
3586. The system ofclaim 3572, further comprising a valve coupled to at least one of the one or more heat sources configured to control pressure within at least a majority of the selected section of the foπnation.
3587. The system ofclaim 3572, further comprising a valve coupled to aproduction well configured to confrol a pressure within at least a majority of the selected section of the formation.
3588. A method of treating a relatively low permeability foπnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion of the foπnation, wherein the one or more heat sources are disposed within one or more open wellbores in the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the formation; and producing a mixture from the formation.
3589. The method ofclaim 3588, wherehi the one or more heat sources comprise at least two heat sources, and wherehi supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
3590. The method ofclaim 3588, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range with a lower pyrolysis temperature of about 250 °C and an upper pyrolysis temperature of about 400 °C.
3591. The method ofclaim 3588, wherein the one or more heat sources comprise electrical heaters.
3592. The method ofclaim 3588, wherein the one or more heat sources comprise surface burners.
3593. The method ofclaim 3588, wherein the one or more heat sources comprise flameless distributed combustors.
3594. The method of clahn 3588, wherein the one or more heat sources comprise natural disfributed combustors.
3595. The method ofclaim 3588, wherein the one or more heat sources are suspended within the one or more open wellbores.
3596. The method of claim 3588, wherein a tube is disposed in at least one of the one or more open wellbores proximate to the heat source, the method further comprising flowing a substantially constant amount of fluid into at least one of the one or more open wellbores through critical flow orifices in the tube.
3597. The method ofclaim 3588, wherein a perforated tube is disposed in at least one of the one or more open wellbores proximate to the heat source, the method further comprising flowing a conosion inhibiting fluid into at least one of the open wellbores through the perforated tube.
3598. The method ofclaim 3588, further comprising coupling an overburden casing to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the foπnation.
3599. The method ofclaim 3588, further comprising coupling an overburden casing to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the fonnation, and wherein the overburden casing comprises steel.
3600. The method ofclaim 3588, further comprising coupling an overburden casing to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.
3601. The method of claim 3588, further comprising coupling an overburden casing to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherehi a packing material is disposed at ajunction of the overburden casing and the at least one of the one or more open wellbores.
3602. The method ofclaim 3588, further comprising coupling an overburden casing to at least one of the one or more open wellbores, wherehi the overburden casing is disposed in an overburden of the foπnation, and wherein the method further comprises inhibiting a flow of fluid between the at least one of the one or more open wellbores and the overburden casing with a packing material.
3603. The method of clahn 3588, further comprising heating at least the portion of the fonnation to substantially pyrolyze at least some hydrocarbons within the fonnation.
3604. The method of claim 3588, further comprising confrolling a pressure and a temperature within at least a majority of the selected section of the foπnation, wherein the pressure is controlled as a function of temperature, or the temperature is confrolled as a function of pressure.
3605. The method ofclaim 3588, furtlier comprising controlling a pressure with the wellbore.
3606. The method ofclaim 3588, further comprising confrolling a pressure within at least a majority of the selected section of the formation with a valve coupled to at least one of the one or more heat sources.
3607. The method of claim 3588, further comprising confrolling a pressure within at least a majority of the selected section of the foπnation with a valve coupled to a production well located in the foπnation.
3608. The method of claim 3588, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1 °C per day during pyrolysis.
3609. The method of claim 3588, wherein providing heat from the one or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from the one or more heat sources, wherein the formation has an average heat capacity(Cv), and wherein the heating pyrolyzes at least some hydrocarbons withhi the selected volmne of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*Cv*pB wherein Pwr is the heating energy/day, h is an average heating rate of the formation, pB is formation bulk density, and wherein the heating rate is less than about 10 °C/day.
3610. The method ofclaim 3588, wherein allowing the heat to transfer from the one or more heat sources to the selected section comprises fransfening heat substantially by conduction.
3611. The method of claim 3588, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
3612. The method ofclaim 3588, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
3613. The method of clahn 3588, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3614. The method of clahn 3588, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1 % by weight to about 15 % by weight of the non-condensable hydrocarbons are olefins.
3615. The method of clahn 3588, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
3616. The method ofclaim 3588, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3617. The method ofclaim 3588, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3618. The method ofclaim 3588, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3619. The method ofclaim 3588, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3620. The method ofclaim 3588, wherein the produced mixture comprises condensable hydrocarbons, and wherehi less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3621. The method ofclaim 3588, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3622. The method ofclaim 3588, wherein the produced mixture comprises a non-condensable component, wherehi the non-condensable component comprises hydrogen, and wherein the hydrogen is greater than about 10 % by volume of the non-condensable component and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
3623. The method of claim 3588, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3624. The method ofclaim 3588, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
3625. The method ofclaim 3588, further comprising controlling a pressure within at least a majority of the selected section of the foimation.
3626. The method ofclaim 3588, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.
3627. The method of claim 3588, further comprising controlling foimation conditions such that the produced mixture comprises a partial pressure of H2 within the mixture greater than about 0.5 bars.
3628. The method ofclaim 3627, wherein the partial pressure of H2 is measured when the mixture is at a production well.
3629. The method ofclaim 3588, wherein controlling formation conditions comprises recfrculating a portion of hydrogen from the mixture into the foπnation.
3630. The method of claim 3588, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.
3631. The method ofclaim 3588, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
3632. The method ofclaim 3588, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
3633. The method ofclaim 3588, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for the production well.
3634. The method ofclaim 3633, wherein at least about 20 heat sources are disposed in the formation for each production well.
3635. The method ofclaim 3588, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
3636. The method of claim 3588, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a ttiangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattem of units.
3637. The method ofclaim 3588, fuither comprising separating the produced mixture into a gas stream and a liquid sfream.
3638. The method ofclaim 3588, further comprising separating the produced mixture into a gas stream and a liquid sfream and separating the liquid sfream into an aqueous stream and a non-aqueous stream.
3639. The method ofclaim 3588, wherein the produced mixture comprises H2S, the method further comprising separating a portion of the H2S from non-condensable hydrocarbons.
3640. The method of claim 3588, wherein the produced mixture comprises C02, the method further comprising separating a portion of the C02 from non-condensable hydrocarbons.
3641. The method ofclaim 3588, wherein the mixture is produced from a production well, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor.
3642. The method ofclaim 3588, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.
3643. The method of claim 3588, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the formation adjacent to the wellbore, and further comprising heating the formation with the heater element to produce the mixture, wherein the mixture comprises a large non-condensable hydrocarbon gas component and H2.
3644. The method ofclaim 3588, wherein the selected section is heated to a minimum pyrolysis temperature of about 270 °C.
3645. The method ofclaim 3588, further comprising maintaining the pressure within the formation above about 2.0 bars absolute to inhibit production of fluids having carbon numbers above 25.
3646. The method ofclaim 3588, further comprising controlling pressure within the foimation in a range from about atmospheric pressure to about 100 bars, as measured at a wellhead of a production well, to control an amount of condensable hydrocarbons within the produced mixture, wherein the pressure is reduced to increase production of condensable hydrocarbons, and wherein the pressure is increased to increase production of non-condensable hydrocarbons.
3647. The method ofclaim 3588, further comprising confrolling pressure within the formation in a range from about atmospheric pressure to about 100 bars, as measured at a wellhead of a production well, to control an API gravity of condensable hydrocarbons within the produced mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.
3648. A mixture produced from a portion of a relatively low permeability fonnation containing heavy hydrocarbons, the mixture, comprising: non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than 5; and wherehi a weight ratio of the hydrocarbons having carbon numbers from 2 through 4, to methane, in the mixture is greater than approximately 1.
3649. The mixture ofclaim 3648, further comprising condensable hydrocarbons, wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
3650. The mixture ofclaim 3648, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3651. The mixture ofclaim 3648, further comprising condensable hydrocarbons, wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
3652. The mixture ofclaim 3648, further comprising condensable hydrocarbons, wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3653. The mixture ofclaim 3648, further comprising condensable hydrocarbons, wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3654. The mixture of claim 3648, further comprising condensable hydrocarbons, wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3655. The mixture ofclaim 3648, further comprising condensable hydrocarbons, wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3656. The mixture ofclaim 3648, further comprising condensable hydrocarbons, wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3657. The mixture of claim 3648, further comprising condensable hydrocarbons, wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons comprise cycloalkanes.
3658. The mixture of claim 3648, wherein the non-condensable hydrocarbons further comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable hydrocarbons, and wherein the hydrogen is less than about 80 % by volume of the non-condensable hydrocarbons.
3659. The mixture ofclaim 3648, further comprising ammonia, wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3660. The mixture ofclaim 3648, further comprising ammonia, wherein the ammonia is used to produce fertilizer.
3661. The mixture of claim 3648, further comprising condensable hydrocarbons, wherein less than about 15 weight % of the condensable hydrocarbons have a carbon number greater than approximately 25.
3662. The mixture ofclaim 3648, further comprising condensable hydrocarbons, wherein the condensable hydrocarbons comprise olefins, and wherein about 0.1 % to about 5 % by weight of the condensable hydrocarbons comprises olefins.
3663. The mixture ofclaim 3648, further comprising condensable hydrocarbons, wherein the condensable hydrocarbons comprises olefins, and wherein about 0.1 % to about 2.5 % by weight of the condensable hydrocarbons comprises olefins.
3664. The mixture of claim 3648, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise H2, and wherein greater than about 5 % by weight of the non-condensable hydrocarbons comprises H2.
3665. The mixture of claim 3648, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise H , and wherein greater than about 15 % by weight of the non-condensable hydrocarbons comprises H2.
3666. The mixture of claim 3648, wherein a weight ratio of hydrocarbons having greater than about 2 carbon atoms, to methane, is greater than about 0.3.
3667. A mixture produced from a portion of a relatively low permeability formation containing heavy hydrocarbons, the mixture comprising: non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than 5, wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1; condensable hydrocarbons; wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons comprises nitrogen; wherehi less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons comprises oxygen; and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons comprises sulfur.
3668. The mixture ofclaim 3667, further comprising ammonia, wherehi greater than about 0.05 % by weight of the produced mixture is ammonia.
3669. The mixture ofclaim 3667, wherein less than about 5 weight % of the condensable hydrocarbons have a carbon number greater than approximately 25.
3670. The mixture of claim 3667, wherein the condensable hydrocarbons comprise olefins, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
3671. The mixture ofclaim 3667, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3672. The mixture ofclaim 3667, wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3673. The mixture of clahn 3667, wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3674. The mixture ofclaim 3667, wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3675. The mixture of claim 3667, wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3676. The mixture of clahn 3667, wherein the non-condensable hydrocarbons comprises hydrogen, and wherein the hydrogen is greater than about 10 % by volume of the non-condensable hydrocarbons and wherein the hydrogen is less than about 80 % by volume of the non-condensable hydrocarbons.
3677. The mixture ofclaim 3667, further comprising ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3678. The mixture of claim 3667, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.
3679. The mixture of claim 3667, wherein the non-condensable hydrocarbons comprise H2, and wherein greater than about 5 % by weight of the non-condensable hydrocarbons comprises H2.
3680. The mixture ofclaim 3667, wherein the non-condensable hydrocarbons comprise H2, and wherein greater than about 15 % by weight of the mixture comprises H2.
3681. The mixture ofclaim 3667, wherein a weight ratio of hydrocarbons having greater than about 2 carbon atoms, to methane, is greater, than about 0.3.
3682. A mixture produced from a portion of a relatively low permeability formation containing heavy hydrocarbons, the mixture comprising: non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than 5, wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1; and ammonia, wherein greater than about 0.5 % by weight of the mixture comprises ammonia.
3683. The mixture ofclaim 3682, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
3684. The mixture ofclaim 3682, wherein the non-condensable hydrocarbons further comprise ethene and ethane, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3685. The mixture of claim 3682, wherein the condensable hydrocarbons further comprise nifrogen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
3686. The mixture ofclaim 3682, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3687. The mixttire of claim 3682, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3688. The mixture ofclaim 3682, wherein the condensable hydrocarbons further comprise aromatic compounds, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3689. The mixture ofclaim 3682, wherein the condensable hydrocarbons further comprise multi-aromatic rings, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3690. The mixture of claim 3682, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3691. The mixture of claim 3682, wherein the condensable hydrocarbons fiirther comprise cycloalkanes, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3692. The mixture ofclaim 3682, wherein the non-condensable hydrocarbons further comprise hydrogen, wherehi the hydrogen is greater than about 10 % by volume of the non-condensable hydrocarbons, and wherein the hydrogen is less than about 80 % by volume of the non-condensable hydrocarbons.
3693. The mixture of claim 3682, wherein the produced mixture further comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3694. The mixture ofclaim 3682, wherein the produced mixture further comprises ammonia, and wherein the ammonia is used to produce fertilizer.
3695. The mixture ofclaim 3682, wherein the condensable hydrocarbons comprise hydrocarbons having a carbon number of greater than approximately 25, and wherein less than about 15 weight % of the hydrocarbons in the mixture have a carbon number greater than approximately 25.
3696. The mixture ofclaim 3682, wherehi the non-condensable hydrocarbons further comprise H2, and wherein greater than about 5 % by weight of the mixture comprises H2.
3697. The mixture ofclaim 3682, wherein the non-condensable hydrocarbons further comprise H2, and wherein greater than about 15 % by weight of the mixture comprises H2.
3698. The mixture ofclaim 3682, wherein the non-condensable hydrocarbons further comprise hydrocarbons having carbon numbers of greater than 2, wherein a weight ratio of hydrocarbons having carbon numbers greater than 2, to methane, is greater than about 0.3.
3699. A mixture produced from a portion of a relatively low permeability formation containing heavy hydrocarbons, the mixture comprising: non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than 5, wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1 ; and condensable hydrocarbons comprising olefins, wherein less than about 10 % by weight of the condensable hydrocarbons comprises olefins.
3700. The mixture ofclaim 3699, wherein the non-condensable hydrocarbons further comprise ethene and ethane, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3701. The mixture ofclaim 3699, wherein the condensable hydrocarbons further comprise nifrogen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
3702. The mixture ofclaim 3699, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3703. The mixture ofclaim 3699, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3704. The mixture ofclaim 3699, wherein the condensable hydrocarbons further comprise aromatic compounds, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3705. The mixture of claim 3699, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3706. The mixture ofclaim 3699, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3707. The mixture ofclaim 3699, wherein the condensable hydrocarbons further comprise cycloalkanes, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3708. The mixture of claim 3699, wherein the non-condensable hydrocarbons further comprise hydrogen, and wherein the hydrogen is greater than about 10 % by volume of the non-condensable hydrocarbons and wherein the hydrogen is less than about 80 % by volume of the non-condensable hydrocarbons.
3709. The mixture ofclaim 3699, wherein the produced mixture further comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3710. The mixture ofclaim 3699, wherein the produced mixture further comprises ammonia, and wherein the ammonia is used to produce fertilizer.
3711. The mixture ofclaim 3699, wherein the condensable hydrocarbons further comprise hydrocarbons having a carbon number of greater than approxhnately 25, and wherein less than about 15 % by weight of the hydrocarbons have a carbon number greater than approximately 25.
3712. The mixttire ofclaim 3699, wherein about 0.1 % to about 5 % by weight of the condensable component comprises olefins.
3713. The mixture ofclaim 3699, wherein about 0.1% to about 2 % by weight of the condensable component comprises olefins.
3714. The mixture ofclaim 3699, wherehi the non-condensable hydrocarbons further comprise H2, and wherein greater than about 5 % by weight of the non-condensable hydrocarbons comprises H2.
3715. The mixture ofclaim 3699, wherein the non-condensable hydrocarbons further comprise H2, and wherein greater than about 15 % by weight of the non-condensable hydrocarbons comprises H2.
3716. The mixture ofclaim 3699, wherein a weight ratio of hydrocarbons having greater than about 2 carbon atoms, to methane, is greater than about 0.3.
3717. A mixture produced from a portion of a relatively low permeability formation containing heavy hydrocarbons, comprising: condensable hydrocarbons, wherein less than about 15 weight % of the condensable hydrocarbons have a carbon number greater than 25.
3718. The mixture ofclaim 3717, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1.
3719. The mixture ofclaim 3717, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
3720. The mixture ofclaim 3717, further comprising non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3721. The mixture ofclaim 3717, wherein the condensable hydrocarbons further comprise nifrogen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
3722. The mixture ofclaim 3717, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3723. The mixture ofclaim 3717, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3724. The mixture of claim 3717, wherein the condensable hydrocarbons further comprise aromatic compounds, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3725. The mixture ofclaim 3717, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3726. The mixture ofclaim 3717, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3727. The mixture ofclaim 3717, wherein the condensable hydrocarbons further comprise cycloalkanes, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3728. The mixture of claim 3717, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise hydrogen, and wherein the hydrogen is greater than about 10 % by volume of the non-condensable hydrocarbons and wherein the hydrogen is less than about 80 % by volume of the non- condensable hydrocarbons.
3729. The mixture ofclaim 3717, further comprising ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3730. The mixture ofclaim 3717, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.
3731. The mixture of claim 3717, wherein the condensable hydrocarbons further comprises olefins, and wherein less than about 10 % by weight of the condensable hydrocarbons comprises olefins.
3732. The mixture ofclaim 3717, wherein the condensable hydrocarbons further comprises olefins, and wherehi about 0.1 % to about 5 % by weight of the condensable hydrocarbons comprises olefins.
3733. The mixture ofclaim 3717, wherein the condensable hydrocarbons further comprises olefins, and wherein about 0.1 % to about 2 % by weight of the condensable hydrocarbons comprises olefins.
3734. The mixture ofclaim 3717, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise H2, wherein greater than about 5 % by weight of the non-condensable hydrocarbons comprises H2.
3735. The mixture of claim 3717, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise H2, wherein greater than about 15 % by weight of the non-condensable hydrocarbons comprises H2.
3736. The mixture ofclaim 3717, wherein a weight ratio of hydrocarbons having greater than about 2 carbon atoms, to methane, is greater than about 0.3.
3737. A mixture produced from a portion of a relatively low permeability formation containing heavy hydrocarbons, comprising: condensable hydrocarbons, wherein less than about 15 % by weight of the condensable hydrocarbons have a carbon number greater than about 25; wherein less than about 1 % by weight of the condensable hydrocarbons, when calculated on an atomic basis, is nifrogen; wherehi less than about 1 % by weight of the condensable hydrocarbons, when calculated on an atomic basis, is oxygen; and wherein less than about 1 % by weight of the condensable hydrocarbons, when calculated on an atomic basis, is sulfur.
3738. The mixture ofclaim 3737, further comprising non-condensable hydrocarbons, wherein the non- condensable component comprises hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1.
3739. The mixture ofclaim 3737, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
3740. The mixture ofclaim 3737, further comprising non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3741. The mixture ofclaim 3737, wherein the condensable hydrocarbons further comprise aromatic compounds, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3742. The mixture of claim 3737, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3743. The mixture of claim 3737, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3744. The mixture ofclaim 3737, wherein the condensable hydrocarbons further comprise cycloalkanes, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3745. The mixture ofclaim 3737, further comprising non-condensable hydrocarbons, and wherein the non- condensable hydrocarbons comprise hydrogen, and wherein greater than about 10 % by volmne and less than about 80 % by volume of the non-condensable component comprises hydrogen.
3746. The mixture of claim 3737, further comprising ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3747. The mixture ofclaim 3737, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.
3748. The mixture ofclaim 3737, wherein the condensable component further comprises olefins, and wherein about 0.1 % to about 5 % by weight of the condensable component comprises olefins.
3749. The mixture ofclaim 3737, wherein the condensable component further comprises olefins, and wherein about 0.1 % to about 2.5 % by weight of the condensable component comprises olefins.
3750. The mixture of claim 3737, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise H2, and wherein greater than about 5 % by weight of the non-condensable hydrocarbons comprises H2.
3751. The mixture ofclaim 3737, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise H2, and wherein greater than about 15 % by weight of the non-condensable hydrocarbons comprises H2.
3752. The mixture ofclaim 3737, further comprising non-condensable hydrocarbons, wherein a weight ratio of compounds within the non-condensable hydrocarbons having greater than about 2 carbon atoms, to methane, is greater than about 0.3.
3753. A mixture produced from a portion of a relatively low permeability fonnation containing heavy hydrocarbons, comprising: condensable hydrocarbons, wherein less than about 15 % by weight of the condensable hydrocarbons have a carbon number greater than 20; and wherein the condensable hydrocarbons comprise olefins, wherein an olefin content of the condensable component is less than about 10 % by weight of the condensable component.
3754. The mixture ofclaim 3753, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1.
3755. The mixture ofclaim 3753, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
3756. The mixture ofclaim 3753, further comprising non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0,15.
3757. The mixture ofclaim 3753, wherein the condensable hydrocarbons further comprise nitrogen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
3758. The mixture ofclaim 3753, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3759. The mixture ofclaim 3753, wherehi the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3760. The mixture of claim 3753, wherein the condensable hydrocarbons further comprise aromatic compounds, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3761. The mixture ofclaim 3753, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3762. The mixture of claim 3753, wherein the condensable hydrocarbons further comprise asphaltenes, and wherehi less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3763. The mixture ofclaim 3753, wherein the condensable hydrocarbons further comprise cycloalkanes, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3764. The mixture of claim 3753, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprises hydrogen, and wherein the hydrogen is about 10 % by volume to about 80 % by volume of the non-condensable hydrocarbons.
3765. The mixture ofclaim 3753, further comprising ammonia, wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3766. The mixture ofclaim 3753, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.
3767. The mixture ofclaim 3753, wherein about 0.1 % to about 5 % by weight of the condensable component comprises olefins.
3768. The mixture ofclaim 3753, wherein about 0.1 % to about 2 % by weight of the condensable component comprises olefins.
3769. The mixture of claim 3753, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise H2, and wherein greater than about 5 % by weight of the non-condensable hydrocarbons comprises H2.
3770. The mixture ofclaim 3753, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise H2, and wherein greater than about 15 % by weight of the non-condensable hydrocarbons comprises H2.
3771. The mixture ofclaim 3753, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 0.3.
3772. A mixture produced from a portion of a relatively low permeability formation containing heavy hydrocarbons, comprising: condensable hydrocarbons, wherein less than about 5 % by weight of the condensable hydrocarbons comprises hydrocarbons having a carbon number greater than about 25; and wherein the condensable hydrocarbons further comprise aromatic compounds, wherein more than about 20 % by weight of the condensable hydrocarbons comprises aromatic compounds.
3773. The mixture of claim 3772, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1.
3774. The mixture ofclaim 3772, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons are olefins.
3775. The mixture ofclaim 3772, further comprising non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3776. The mixture of claim 3772, wherein the condensable hydrocarbons further comprise nitrogen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
3777. The mixture of claim 3772, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3778. The mixture ofclaim 3772, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3779. The mixture of claim 3772, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3780. The mixture ofclaim 3772, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3781. The mixture ofclaim 3772, wherein the condensable hydrocarbons comprise cycloalkanes, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3782. The mixture of claim 3772, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise hydrogen, and wherein the hydrogen is greater than about 10 % by volume and less than about 80 % by volume of the non-condensable hydrocarbons.
3783. The mixture of claim 3772, further comprising ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3784. The mixture ofclaim 3772, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.
3785. The mixture of clahn 3772, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1 % to about 5 % by weight of the condensable hydrocarbons comprises olefins.
3786. The mixture ofclaim 3772, wherein the condensable hydrocarbons further comprises olefins, and wherein about 0.1 % to about 2 % by weight of the condensable hydrocarbons comprises olefins.
3787. The mixture of clahn 3772, wherein the condensable hydrocarbons further comprises multi-ring aromatic compounds, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatic compounds.
3788. The mixture ofclaim 3772, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise H2, and wherein greater than about 5 % by weight of the non-condensable hydrocarbons comprises H2.
3789. The mixture of claim 3772, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprise H2, and wherein greater than about 15 % by weight of the non-condensable hydrocarbons comprises H2.
3790. The mixture ofclaim 3772, further comprising non-condensable hydrocarbons, wherein the non- condensable hydrocarbons comprises hydrocarbons having carbon numbers of less than 5, and wherehi a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 0.3.
3791. A mixture produced from a portion of a relatively low permeability formation containing heavy hydrocarbons, comprising: non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than about 5, wherein a weight ratio of the hydrocarbons having carbon number from 2 through 4, to methane, in the mixture is greater than approximately 1; wherein the non-condensable hydrocarbons further comprise H2, wherein greater than about 15 % by weight of the non-condensable hydrocarbons comprises H2; and condensable hydrocarbons, comprising: olefins, wherein less than about 10 % by weight of the condensable hydrocarbons comprises olefins; and aromatic compounds, wherein greater than about 20 % by weight of the condensable hydrocarbons comprises aromatic compounds.
3792. The mixture ofclaim 3791, wherein the non-condensable hydrocarbons further comprise ethene and ethane, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3793. The mixture of clahn 3791, wherein the condensable hydrocarbons further comprise nifrogen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
3794. The mixture ofclaim 3791, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherehi less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3795. The mixture ofclaim 3791, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3796. The mixture ofclaim 3791, wherein the condensable hydrocarbons comprise multi-ring aromatics, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3797. The mixture ofclaim 3791, wherein the condensable hydrocarbons comprise asphaltenes, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3798. The mixture ofclaim 3791, wherein the condensable hydrocarbons comprise cycloalkanes, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3799. The mixture ofclaim 3791, wherein the non-condensable hydrocarbons further comprises hydrogen, and wherein greater than about 10 % by volume and less than about 80 % by volume of the non-condensable hydrocarbons.
3800. The mixture of clahn 3791, further comprising ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3801. The mixture ofclaim 3791, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.
3802. The mixture ofclaim 3791, wherein the condensable hydrocarbons further comprise hydrocarbons having a carbon number of greater than approximately 25, wherein less than about 15 % by weight of the hydrocarbons have a carbon number greater than approximately 25.
3803. The mixture ofclaim 3791, wherein about 0.1 % to about 5 % by weight of the condensable hydrocarbons comprises olefins.
3804. The mixture ofclaim 3791, wherein about 0.1 % to about 2 % by weight of the condensable hydrocarbons comprises olefins.
3805. The mixture ofclaim 3791, wherein the mixture comprises hydrocarbons having greater than about 2 carbon atoms, and wherein the weight ratio of hydrocarbons having greater than about 2 carbon atoms to methane is greater than about 0.3.
3806. A mixture produced from a portion of a relatively low permeability foπnation containing heavy hydrocarbons, comprising: condensable hydrocarbons, wherein less than about 5 % by weight of the condensable hydrocarbons comprises hydrocarbons having a carbon number greater than about 25; wherein the condensable hydrocarbons further comprise: olefins, wherein less than about 10 % by weight of the condensable hydrocarbons comprises olefins; and aromatic compounds, wherein greater than about 30 % by weight of the condensable hydrocarbons comprises aromatic compounds; and non-condensable hydrocarbons comprising H2, wherein greater than about 15 % by weight of the non- condensable hydrocarbons comprises H2.
3807. The mixture ofclaim 3806, wherein the non-condensable hydrocarbons further comprises hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon nmnbers from 2 through 4, to methane, is greater than approximately 1.
3808. The mixture ofclaim 3806, wherein the non-condensable hydrocarbons comprise ethene and ethane, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3809. The mixture ofclaim 3806, wherein the condensable hydrocarbons further comprise nitrogen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
3810. The mixture ofclaim 3806, wherehi the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3811. The mixture ofclaim 3806, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3812. The mixture of claim 3806, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3813. The mixture of clahn 3806, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3814. The mixture ofclaim 3806, wherein the condensable hydrocarbons comprise cycloalkanes, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3815. The mixture of claim 3806, wherein greater than about 10 % by volume and less than about 80 % by volume of the non-condensable hydrocarbons is hydrogen.
3816. The mixture ofclaim 3806, further comprising ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3817. The mixture ofclaim 3806, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.
3818. The mixture of clahn 3806, wherein about 0.1 % to about 5 % by weight of the condensable hydrocarbons comprises olefins.
3819. The mixture ofclaim 3806, wherein about 0.1 % to about 2 % by weight of the condensable hydrocarbons comprises olefins.
3820. The mixture ofclaim 3806, wherein the mixture comprises hydrocarbons having greater than about 2 carbon atoms, and wherehi the weight ratio of hydrocarbons having greater than about 2 carbon atoms to methane is greater than about 0.3.
3821. A mixture of condensable hydrocarbons produced from a portion of a relatively low permeability formation containing heavy hydrocarbons, comprising: olefins, wherein about 0.1 % by weight to about 15 % by weight of the condensable hydrocarbons comprises olefins; and asphaltenes, wherein less than about 0.1 % by weight of the condensable hydrocarbons comprises asphaltenes.
3822. The mixture ofclaim 3821, wherein the condensable hydrocarbons further comprises hydrocarbons having a carbon number of greater than approximately 25, and wherein less than about 15 weight % of the hydrocarbons in the mixture have a carbon number greater than approximately 25.
3823. The mixture of claim 3821 , wherein about 0.1 % by weight to about 5 % by weight of the condensable hydrocarbons comprises olefins.
3824. The mixture of claim 3821 , wherein the condensable hydrocarbons further comprises non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise ethene and ethane, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3825. The mixture of claim 3821 , wherein the condensable hydrocarbons further comprises nitrogen, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
3826. The mixture ofclaim 3821, wherein the condensable hydrocarbons further comprises oxygen, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3827. The mixture ofclaim 3821, wherein the condensable hydrocarbons further comprises sulfur, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3828. The mixture of clahn 3821, wherein the condensable hydrocarbons further comprises aromatic compounds, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3829. The mixture ofclaim 3821, wherein the condensable hydrocarbons further comprises multi-ring aromatics, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3830. The mixture ofclaim 3821, wherein the condensable hydrocarbons further comprises cycloalkanes, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3831. The mixture of claim 3821, wherein the condensable hydrocarbons comprises non-condensable hydrocarbons, and wherein the non-condensable hydrocarbons comprise hydrogen, and wherein the hydrogen is greater than about 10 % by volume of the non-condensable hydrocarbons and wherein the hydrogen is less than about 80 % by volume of the non-condensable hydrocarbons.
3832. The mixture ofclaim 3821, further comprising ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3833. The mixture ofclaim 3821, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.
3834. The mixture of claim 3821 , wherein about 0.1 % by weight to about 2 % by weight of the condensable hydrocarbons comprises olefins.
3835. A mixture of condensable hydrocarbons produced from a portion of a relatively low permeability formation containing heavy hydrocarbons, comprising: olefins, wherein about 0.1 % by weight to about 2 % by weight of the condensable hydrocarbons comprises olefins;
multi-ring aromatics, wherein less than about 4 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings
3836. The mixture ofclaim 3835, further comprising hydrocarbons having a carbon number of greater than approximately 25, wherein less than about 5 weight % of the hydrocarbons in the mixture have a carbon number greater than approximately 25.
3837. The mixture ofclaim 3835, wherein the condensable hydrocarbons further comprises nitrogen, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
3838. The mixture ofclaim 3835, wherein the condensable hydrocarbons further comprises oxygen, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3839. The mixture o claim 3835, wherein the condensable hydrocarbons further comprises sulfur, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3840. The mixture ofclaim 3835, wherein the condensable hydrocarbons further comprises aromatic compounds, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3841. The mixture ofclaim 3835, wherein the condensable hydrocarbons further comprises condensable hydrocarbons, and wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3842. The mixture ofclaim 3835, wherein the condensable hydrocarbons further comprises cycloalkanes, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3843. The mixture ofclaim 3835, further comprising ammonia, wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3844. The mixture of claim 3835, further comprising ammonia, wherein the ammonia is used to produce fertilizer.
3845. A mixture produced from a portion of a relatively low permeability foimation containing heavy hydrocarbons, comprising: non-condensable hydrocarbons and H2, wherein greater than about 10% by volume of the non-condensable hydrocarbons and H2 comprises H2; ammonia and water, wherein greater than about 0.5 % by weight of the mixture comprises ammonia; and condensable hydrocarbons.
3846. The mixture of claim 3845, wherein the non-condensable hydrocarbons further comprise hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of the hydrocarbons having carbon numbers from 2 through 4 to methane, in the mixture is greater than approximately 1.
3847. The mixture ofclaim 3845, wherein greater than about 0.1 % by weight of the condensable hydrocarbons are olefins, and wherein less than about 15 % by weight of the condensable hydrocarbons are olefins.
3848. The mixture ofclaim 3845, wherein the non-condensable hydrocarbons further comprise ethene and ethane, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is greater than about 0.001, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15.
3849. The mixture ofclaim 3845, wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nifrogen.
3850. The mixture of claim 3845, wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3851. The mixture ofclaim 3845, wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3852. The mixture ofclaim 3845, wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3853. The mixture ofclaim 3845, wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3854. The mixture ofclaim 3845, wherein less than about 0.3 % by weight of the condensable hydrocarbons are asphaltenes.
3855. The mixture ofclaim 3845, wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3856. The mixture ofclaim 3845, wherein the H2 is less than about 80 % by volume of the non-condensable hydrocarbons and H2.
3857. The mixture ofclaim 3845, wherein the condensable hydrocarbons further comprise sulfur containing compounds.
3858. The mixture ofclaim 3845, wherein the ammonia is used to produce fertilizer.
3859. The mixture ofclaim 3845, wherein less than about 5% of the condensable hydrocarbons have carbon numbers greater than 25.
3860. The mixture ofclaim 3845, wherein the condensable hydrocarbons comprise olefins, wherein greater than about about 0.001 % by weight of the condensable hydrocarbons comprise olefins, and wherein less than about 15% by weight of the condensable hydrocarbons comprise olefins.
3861. The mixture of claim 3845, wherein the condensable hydrocarbons comprise olefins, wherein greater than about about 0.001 % by weight of the condensable hydrocarbons comprise olefins, and wherein less than about 10% by weight of the condensable hydrocarbons comprise olefins.
3862. The mixture ofclaim 3845, wherein the condensable hydrocarbons further comprise nitrogen containing compounds.
3863. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
3864. The method ofclaim 3863, wherein three or more of the heat sources are located in the foπnation in a plurality of the units, and wherein the plurality of units are repeated over an area of the foπnation to form a repetitive pattern of units.
3865. The method ofclaim 3863, wherein three or more of the heat sources are located in the foπnation in a plurality of the units, wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units, and wherein a ratio of heat sources in the repetitive pattern of units to production wells in the repetitive pattern is greater than approximately 5.
3866. The method ofclaim 3863, wherein three or more of the heat sources are located in the formation in a plurality of the units, wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units, wherein three or more production wells are located within an area defined by the plurality of units, wherein the three or more production wells are located in the formation in a unit of production wells, and wherein the unit of production wells comprises a friangular pattern.
3867. The method ofclaim 3863, wherein three or more of the heat sources are located in the formation in a plurality of the units, wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units, wherehi three or more injection wells are located within an area defined by the plurality of units, wherein the three or more injection wells are located in the formation in a unit of injection wells, and wherein the unit of injection wells comprises a friangular pattern.
3868. The method ofclaim 3863, wherein three or more of the heat sources are located in the formation in a plurality of the units, wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units, wherein three or more production wells and three or more injection wells are located within an area defined by the plurality of units, wherein the three or more production wells are located in the formation in a unit of production wells, wherein the unit of production wells comprises a first friangular pattern, wherein the three or more injection wells are located in the fonnation in a unit of injection wells, wherein the unit of injection wells comprises a second triangular pattern, and wherein the first triangular pattern is substantiaUy different than the second triangular pattern.
3869. The method ofclaim 3863, wherein three or more of the heat sources are located in the formation in a plurality of the units, wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units, wherein three or more monitoring wells are located within an area defined by the plurality of units, wherein the three or more monitoring wells are located in the formation in a unit of monitoring wells, and wherein the unit of monitoring wells comprises a ttiangular pattern.
3870. The method ofclaim 3863, wherein a production well is located in an area defined by the unit of heat sources.
3871. The method ofclaim 3863, wherein three or more of the heat sources are located in the formation in a first unit and a second unit, wherein the first unit is adjacent to the second unit, and wherein the first unit is inverted with respect to the second unit.
3872. The method ofclaim 3863, wherein a distance between each of the heat sources in the unit of heat sources varies by less than about 20 %.
3873. The method ofclaim 3863, wherein a distance between each of the heat sources in the unit of heat sources is approximately equal.
3874. The method ofclaim 3863, wherein providing heat from three or more heat sources comprises substantially uniformly providing heat to at least the portion of the formation.
3875. The method ofclaim 3863, wherein the heated portion comprises a substantially uniform temperature disttibution.
3876. The method of claim 3863, wherein the heated portion comprises a substantially uniform temperature disttibution, and wherein a difference between a highest temperature in the heated portion and a lowest temperature in the heated portion comprises less than about 200 °C.
3877. The method ofclaim 3863, wherein a temperature at an outer lateral boundary of the triangular pattern and a temperature at a center of the friangular pattern are approximately equal.
3878. The method ofclaim 3863, wherein a temperature at an outer lateral boundary of the friangular pattern and a temperature at a center of the triangular pattern increase substantially linearly after an initial period of time, and wherein the initial period of time comprises less than approximately 3 months.
3879. The method ofclaim 3863, wherein a time required to increase an average temperature of the heated portion to a selected temperature with the friangular pattern of heat sources is substantially less than a time requfred to increase the average temperature of the heated portion to the selected temperature with a hexagonal pattern of heat sources, and wherein a space between each of the heat sources in the friangular pattern is approximately equal to a space between each of the heat sources in the hexagonal pattern.
3880. The method ofclaim 3863, wherein a time requfred to increase a temperature at a coldest point within the heated portion to a selected temperature with the friangular pattern of heat sources is substantially less than a time required to increase a temperature at the coldest point within the heated portion to the selected temperature with a hexagonal pattern of heat sources, and wherein a space between each of the heat sources in the triangular pattern is approximately equal to a space between each of the heat sources in the hexagonal pattern.
3881. The method ofclaim 3863, wherein a time requfred to increase a temperature at a coldest point withhi the heated portion to a selected temperature with the triangular pattern of heat sources is substantially less than a time required to increase a temperature at the coldest point within the heated portion to the selected temperature with a hexagonal pattern of heat sources, and wherehi a number of heat sources per unit area in the ttiangular pattern is equal to the number of heat sources per unit are in the hexagonal pattern of heat sources.
3882. The method ofclaim 3863, wherein a time required to increase a temperature at a coldest point within the heated portion to a selected temperature with the ttiangular pattern of heat sources is substantially equal to a time requfred to increase a temperature at the coldest point within the heated portion to the selected temperature with a hexagonal pattern of heat sources, and wherein a space between each of the heat sources in the friangular pattern is approximately 5 m greater than a space between each of the heat sources in the hexagonal pattern.
3883. The method ofclaim 3863, wherein providing heat from three or more heat sources to at least the portion of formation comprises: heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons from three or more of the heat sources, wherein the formation has an average heat capacity (Cv), and wherein heat from three or more of the heat sources pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day provided to the volume is equal to or less than Pwr, wherein Pwr is calculated by the equation:
Pwr = h*V*C *pB wherein Pwr is the heating energy/day, h is an average heating rate of the foπnation, pB is formation bulk density, and wherein the heating rate is less than about 10°C/day.
3884. The method ofclaim 3863, wherein three or more of the heat sources comprise elecfrical heaters.
3885. The method ofclaim 3863, wherein three or more of the heat sources comprise surface burners.
3886. The method ofclaim 3863, wherein three or more of the heat sources comprise flameless disfributed combustors.
3887. The method ofclaim 3863, wherein three or more of the heat sources comprise natural disfributed combustors.
3888. The method ofclaim 3863, further comprising: allowing the heat to fransfer from three or more of the heat sources to a selected section of the formation such that heat from three or more of the heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation; and producing a mixture of fluids from the formation.
3889. The method ofclaim 3888, further comprising controlling a temperature withhi at least a majority of the selected section of the foπnation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.
3890. The method ofclaim 3888, further comprising confrolling the heat such that an average heating rate of the selected section is less than about 1.0° C per day during pyrolysis.
3891. The method ofclaim 3888, wherein allowing the heat to fransfer from three or more of the heat sources to the selected section comprises transferring heat substantially by conduction.
3892. The method ofclaim 3888, wherein the produced mixture comprises an API gravity of at least 25°.
3893. The method ofclaim 3888, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.
3894. The method ofclaim 3888, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.
3895. The method ofclaim 3888, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.
3896. The method ofclaim 3888, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.
3897. The method ofclaim 3888, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1 % by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.
3898. The method ofclaim 3888, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20 % by weight of the condensable hydrocarbons are aromatic compounds.
3899. The method ofclaim 3888, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5 % by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.
3900. The method ofclaim 3888, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.1% by weight of the condensable hydrocarbons are asphaltenes.
3901. The method ofclaim 3888, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5 % by weight to about 30 % by weight of the condensable hydrocarbons are cycloalkanes.
3902. The method ofclaim 3888, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10 % by volume of the non-condensable component, and wherein the hydrogen is less than about 80 % by volume of the non-condensable component.
3903. The method of claim 3888, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05 % by weight of the produced mixture is ammonia.
3904. The method ofclaim 3888, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.
3905. The method ofclaim 3888, further comprising controlling foπnation conditions to produce a mixture of hydrocarbon fluids and H2, wherein a partial pressure of H2 within the mixture is greater than about 2.0 bars absolute.
3906. The method ofclaim 3888, further comprishig altering a pressure within the formation to inhibit production of hydrocarbons from the foπnation having carbon numbers greater than about 25.
3907. The method ofclaim 3888, further comprising controlling formation conditions by recirculating a portion ofhydrogen from the mixture into the foπnation.
3908. The method of claim 3888, further comprising: providing hydrogen (H2) to the heated section to hydrogenate hydrocarbons within the section; and heating a portion of the section with heat from hydrogenation.
3909. The method ofclaim 3888, further comprising: producing hydrogen from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
3910. The method ofclaim 3888, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heat sources are disposed in the formation for each production well.
3911. The method of claim 3910, wherein at least about 20 heat sources are disposed in the formation for each production well.
3912. The method of clahn 3888, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
3913. The method ofclaim 3888, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherehi a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
3914. A method for in situ production of synthesis gas from a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a section of the foπnation to a temperature sufficient to allow synthesis gas generation, wherein a permeability of the section is substantially uniform; providing a synthesis gas generating fluid to the section to generate synthesis gas; and removing synthesis gas from the foimation.
3915. The method of clahn 3914, wherein the temperature sufficient to allow synthesis gas generation ranges from approximately 400 °C to approxhnately 1200 °C.
3916. The method ofclaim 3914, further comprismg heating the section when providing the synthesis gas generating fluid to inhibit temperature decrease in the section due to synthesis gas generation.
3917. The method of clahn 3914, wherehi heating the section comprises converting an oxidizing fluid into a portion of the section, wherein the temperature within the section is above a temperature sufficient to support oxidation of carbon within the section with the oxidizing fluid, and reacting the oxidizhig fluid with carbon in the section to generate heat within the section.
3918. The method of clahn 3917, wherein the oxidizing fluid comprises air.
3919. The method ofclaim 3918, wherein an amount of the oxidizing fluid convected into the section is configured to inhibit foπnation of oxides of nifrogen by maintaining a reaction temperature below a temperature sufficient to produce oxides of nitrogen compounds.
3920. The method ofclaim 3914, wherein heating the section comprises diffusing an oxidizing fluid to reaction zones adjacent to wellbores within the foimation, oxidizing carbon within the reaction zone to generate heat, and transfening the heat to the section.
3921. The method ofclaim 3914, wherein heating the section comprises heating the section by transfer of heat from one or more of electrical heaters.
3922. The method ofclaim 3914, wherein heating the section to a temperature sufficient to allow synthesis gas generation and providing a synthesis gas generating fluid to the section comprises introducing steam into the section to heat the foimation and to generate synthesis gas.
3923. The method of claim 3914, further comprising controlling the heating of the section and provision of the synthesis gas generating fluid to maintain a temperature within the section above the temperature sufficient to generate synthesis gas.
3924. The method ofclaim 3914, further comprising: monitoring a composition of the produced synthesis gas; and confrolling heating of the section and provision of the synthesis gas generating fluid to maintain the composition of the produced synthesis gas within a selected range.
3925. The method of claim 3924, wherein the selected range comprises a ratio of H2 to CO of about 2:1.
3926. The method of claim 3914, wherein the synthesis gas generating fluid comprises liquid water.
3927. The method of clahn 3914, wherein the synthesis gas generating fluid comprises steam.
3928. The method of claim 3914, wherein the synthesis gas generating fluid comprises water and carbon dioxide, and wherein the carbon dioxide inhibits production of carbon dioxide from hydrocarbon containing material within the section.
3929. The method ofclaim 3928, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the fonnation.
3930. The method ofclaim 3914, wherein the synthesis gas generathig fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.
3931. The method of claim 3930, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.
3932. The method ofclaim 3914, wherein providing the synthesis gas generating fluid to the section comprises raising a water table of the formation to allow water to flow into the section.
3933. The method ofclaim 3914, wherein the synthesis gas is removed from a producer well equipped with a heating source, and wherein a portion of the heating source adjacent to a synthesis gas producing zone operates at a substantially constant temperature to promote production of the synthesis gas wherein the synthesis gas has a selected composition.
3934. The method ofclaim 3933, wherein the substantially constant temperature is about 700 °C, and wherein the selected composition has a H2 to CO ratio of about 2 : 1.
3935. The method ofclaim 3914, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within the section to increase a H2 concenfration of the generated synthesis gas.
3936. The method of claim 3914, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within the section to increase an energy content of the synthesis gas removed from the formation.
3937. The method ofclaim 3914, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.
3938. The method ofclaim 3914, further comprising generating electricity from the synthesis gas using a fuel cell.
3939. The method ofclaim 3914, further comprising generating electricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the fonnation.
3940. The method ofclaim 3914, further comprising using a portion of the synthesis gas as a combustion fuel to heat the formation.
3941. The method ofclaim 3914, further comprising converting at least a portion of the produced synthesis gas to condensable hydrocarbons using a Fischer-Tropsch synthesis process.
3942. The method ofclaim 3914, further comprising converting at least a portion of the produced synthesis gas to methanol.
3943. The method ofclaim 3914, further comprising converting at least a portion of the produced synthesis gas to gasoline.
3944. The method ofclaim 3914, further comprising converting at least a portion of the synthesis gas to methane using a catalytic methanation process.
3945. The method ofclaim 3914, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a ttiangular pattern.
3946. The method of claim 3914, further comprising providing heat from three or more heat sources to at least a portion of the foimation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
3947. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to increase a temperature of the portion to a temperature sufficient to allow synthesis gas generation; providing a synthesis gas generating fluid to at least the portion of the selected section, wherein the synthesis gas generating fluid comprises carbon dioxide; obtaining a portion of the carbon dioxide of the synthesis gas generating fluid from the formation; and producing synthesis gas from the foimation.
3948. The method ofclaim 3947, wherein the temperature sufficient to allow synthesis gas generation is within a range from about 400 °C to about 1200 °C.
3949. The method ofclaim 3947, further comprising using a second portion of the separated carbon dioxide as a flooding agent to produce hydrocarbon bed methane from a relatively low permeability formation containing heavy hydrocarbons.
3950. The method ofclaim 3949, wherein the relatively low peπneability foπnation containing heavy hydrocarbons is a deep relatively low permeability formation containing heavy hydrocarbons over 760 m below ground surface.
3951. The method of claim 3949, wherein the relatively low permeability fonnation containing heavy hydrocarbons adsorbs some of the carbon dioxide to sequester the carbon dioxide.
3952. The method of claim 3947, further comprising using a second portion of the separated carbon dioxide as a flooding agent for enhanced oil recovery.
3953. The method ofclaim 3947, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons undergo a reaction within the selected section to increase a H2 concenfration within the produced synthesis gas.
3954. The method of clahn 3947, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within the selected section to increase an energy content of the produced synthesis gas.
3955. The method of claim 3947, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.
3956. The method of claim 3947, further comprising generating electricity from the synthesis gas using a fuel cell.
3957. The method of claim 3947, further comprising generating elecfricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent portion of the formation.
3958. The method of claim 3947, further comprising using a portion of the synthesis gas as a combustion fuel for heating the fonnation.
3959. The method of claim 3947, further comprising converting at least a portion of the produced synthesis gas to condensable hydrocarbons using a Fischer-Tropsch synthesis process.
3960. The method of claim 3947, further comprising converting at least a portion of the produced synthesis gas to methanol.
3961. The method ofclaim 3947, further comprising converting at least a portion of the produced synthesis gas to gasoline.
3962. The method ofclaim 3947, further comprising converting at least a portion of the synthesis gas to methane using a catalytic methanation process.
3963. The method ofclaim 3947, wherein a temperature of the one or more heat sources is maintained at a temperature of less than approximately 700 °C to produce a synthesis gas having a ratio of H2 to carbon monoxide of greater than about 2.
3964. The method ofclaim 3947, wherein a temperature of the one or more heat sources is maintained at a temperature of greater than approximately 700 °C to produce a synthesis gas having a ratio of H2 to carbon monoxide of less than about 2.
3965. The method ofclaim 3947, wherein a temperature of the one or more heat sources is maintained at a temperature of approximately 700 °C to produce a synthesis gas having a ratio of H2 to carbon monoxide of approximately 2.
3966. The method ofclaim 3947, wherein a heat source of the one or more of heat sources comprises an electrical heater.
3967. The method of clahn 3947, wherein a heat source of the one or more heat sources comprises a natural distributed heater.
3968. The method ofclaim 3947, wherein a heat source of the one or more heat sources comprises a flameless distributed combustor (FDC) heater, and wherein fluids are produced from the wellbore of the FDC heater through a conduit positioned within the wellbore.
3969. The method of claim 3947, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
3970. The method of claim 3947, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
3971. A method of in situ synthesis gas production, comprising: providing heat from one or more flameless distributed combustor heaters to at least a first portion of a relatively low permeability foimation containing heavy hydrocarbons; allowing the heat to transfer from the one or more heaters to a selected section of the formation to raise a temperature of the selected section to a temperature sufficient to generate synthesis gas;
infroducing a synthesis gas producing fluid into the selected section to generate synthesis gas; and removing synthesis gas from the formation.
3972. The method ofclaim 3971, wherein the one or more heaters comprise at least two heaters, and wherein supeφosition of heat from at least the two heaters raises a temperature of the selected section to a temperature sufficient to generate synthesis gas.
3973. The method of claim 3971, further comprising producing the synthesis gas from the formation under pressure, and generating elecfricity from the produced synthesis gas by passing the produced synthesis gas through a turbine.
3974. The method ofclaim 3971, further comprising producing pyrolyzation products from the foimation when raising the temperature of the selected section to the temperature sufficient to generate synthesis gas.
3975. The method ofclaim 3971, further comprising separating a portion of carbon dioxide from the removed synthesis gas, and storing the carbon dioxide within a spent portion of the formation.
3976. The method ofclaim 3971, further comprising storing carbon dioxide within a spent portion of the formation, wherein an amount of carbon dioxide stored within the spent portion of the formation is equal to or greater than an amount of carbon dioxide within the removed synthesis gas.
3977. The method ofclaim 3971, further comprising separating a portion of H2 from the removed synthesis gas; and using a portion of the separated H2 as fuel for the one or more heaters.
3978. The method ofclaim 3971, further comprising using a portion of exhaust products from the one or more heaters as a portion of the synthesis gas producing fluid.
3979. The method ofclaim 3971, further comprising using a portion of the removed synthesis gas with a fuel cell to generate electricity.
3980. The method ofclaim 3979, wherein the fuel cell produces steam, and wherein a portion of the steam is used as a portion of the synthesis gas producing fluid.
3981. The method ofclaim 3979, wherein the fuel cell produces carbon dioxide, and wherein a portion of the carbon dioxide is infroduced into the formation to react with carbon within the formation to produce carbon monoxide.
3982. The method ofclaim 3979, wherein the fuel cell produces carbon dioxide, and further comprising storing an amount of carbon dioxide within a spent portion of the foimation equal or greater to an amount of the carbon dioxide produced by the fuel cell.
3983. The method of clahn 3971, further comprising using a portion of the removed synthesis gas as a feed product for foimation of hydrocarbons.
3984. The method of claim 3971 , wherein the synthesis gas producing fluid comprises hydrocarbons having carbon numbers less than 5, and wherehi the hydrocarbons crack within the formation to increase an amount of H2 within the generated synthesis gas.
3985. The method ofclaim 3971, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
3986. The method ofclaim 3971, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
3987. A method of treating a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a portion of the formation with one or more electrical heaters to a temperature sufficient to pyrolyze hydrocarbons within the portion; producing pyrolyzation fluid from the formation; separating a fuel cell feed stteam from the pyrolyzation fluid; and directing the fuel cell feed sfream to a fuel cell to produce elecfricity.
3988. The method ofclaim 3987, wherein the fuel cell is a molten carbonate fuel cell.
3989. The method of claim 3987, wherein the fuel cell is a solid oxide fuel cell.
3990. The method of claim 3987, further comprising using a portion of the produced electticity to power the elecfrical heaters.
3991. The method ofclaim 3987, wherein the fuel cell feed sfream comprises H2 and hydrocarbons having a carbon number of less than 5.
3992. The method of claim 3987, wherein the fuel cell feed stteam comprises H2 and hydrocarbons having a carbon number of less than 3.
3993. The method ofclaim 3987, further comprising hydrogenating the pyrolyzation fluid with aportion of H2 from the pyrolyzation fluid.
3994. The method of claim 3987, wherein the hydrogenation is done in situ by directing the H2 into the foimation.
3995. The method ofclaim 3987, wherein the hydrogenation is done in a surface unit.
3996. The method of claim 3987, further comprising directing hydrocarbon fluid having carbon numbers less than 5 adjacent to at least one of the electrical heaters, cracking a portion of the hydrocarbons to produce H2, and producing a portion of the hydrogen from the formation.
3997. The method of claim 3996, further comprising directing an oxidizhig fluid adjacent to at least the one of the elecfrical heaters, oxidizing coke deposited on or near the at least one of the elecfrical heaters with the oxidizing fluid.
3998. The method of claim 3987, further comprising storing C02 from the fuel cell within the formation.
3999. The method of claim 3998, wherein the C02 is adsorbed to carbon material within a spent portion of the formation.
4000. The method ofclaim 3987, further comprising cooling the portion to form a spent portion of formation. .
4001. The method of claim 4000, wherein cooling the portion comprises introducing water into the portion to produce steam, and removing steam from the formation.
4002. The method ofclaim 4001, further comprising using a portion of the removed steam to heat a second portion of the formation.
4003. The method ofclaim 4001, further comprising using a portion of the removed steam as a synthesis gas producing fluid in a second portion of the formation.
4004. The method ofclaim 3987, further comprising: heating the portion to a temperature sufficient to support generation of synthesis gas after production of the pyrolyzation fluids; infroducing a synthesis gas producing fluid into the portion to generate synthesis gas; and removing a portion of the synthesis gas from the formation.
4005. The method ofclaim 4004, further comprising producing the synthesis gas from the formation under pressure, and generating electricity from the produced synthesis gas by passing the produced synthesis gas through a turbine.
4006. The method ofclaim 4004, further comprising using a first portion of the removed synthesis gas as fuel cell feed.
4007. The method ofclaim 4004, further comprising producing steam from operation of the fuel cell, and using the steam as part of the synthesis gas producing fluid.
4008. The method of claim 4004, further comprising using carbon dioxide from the fuel cell as a part of the synthesis gas producing fluid.
4009. The method of claim 4004, further comprising using a portion of the synthesis gas to produce hydrocarbon product.
4010. The method ofclaim 4004, further comprising cooling the portion to form a spent portion of formation.
4011. The method of claim 4010, wherein cooling the portion comprises introducing water into the portion to produce steam, and removing steam from the formation.
4012. The method ofclaim 4011, further comprising using a portion of the removed steam to heat a second portion of the formation.
4013. The method ofclaim 4011, further comprising using a portion of the removed steam as a synthesis gas producing fluid in a second portion of the formation.
4014. The method ofclaim 3987, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
4015. The method ofclaim 3987, further comprising providing heat from three or more heat sources to at least a portion of the foimation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a friangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
4016. A method for in situ production of synthesis gas from a relatively low permeability foπnation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to ttansfer from the one or more heat sources to a selected section of the formation such that the heat from the one or more heat sources pyrolyzes at least some of the hydrocarbons within the selected section of the formation; producing pyrolysis products from the formation; heating at least a portion of the selected section to a temperature sufficient to generate synthesis gas;
providing a synthesis gas generating fluid to at least the portion of the selected section to generate synthesis gas; and producing a portion of the synthesis gas from the foimation.
4017. The method ofclaim 4016, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
4018. The method of claim 4016, further comprising heating at least the portion of the selected section when providing the synthesis gas generating fluid to inhibit temperature decrease within the selected section during synthesis gas generation.
4019. The method ofclaim 4016, wherein the temperature sufficient to allow synthesis gas generation is within a range from approximately 400 °C to approximately 1200 °C.
4020. The method ofclaim 4016, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: heating zones adjacent to wellbores of one or more heat sources with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid; introducing the oxidizing fluid to the zones substantially by diffusion; allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and fransfening heat from the zones to the selected section.
4021. The method of claim 4016, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: infroducing an oxidizing fluid into the formation through a wellbore; transporting the oxidizing fluid substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and reacting the oxidizing fluid within the portion of the selected section to generate heat and raise the temperature of the portion.
4022. The method of claim 4016, wherein the one or more heat sources comprise one or more electrical heaters disposed in the foπnation.
4023. The method of claim 4016, wherein the one or more heat sources comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the foπnation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4024. The method of claim 4016, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a synthesis gas generating fluid to at least the portion of the selected section comprises infroducing steam into the portion.
4025. The method of claim 4016, further comprising controlling the heating of at least the portion of selected section and provision of the synthesis gas generathig fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.
4026. The method ofclaim 4016, further comprising: monitoring a composition of the produced synthesis gas; and controlling heating of at least the portion of selected section and provision of the synthesis gas generating fluid to maintain the composition of the produced synthesis gas within a desired range.
4027. The method of claim 4016, wherein the synthesis gas generathig fluid comprises liquid water.
4028. The method ofclaim 4016, wherein the synthesis gas generating fluid comprises steam.
4029. The method ofclaim 4016, wherein the synthesis gas generathig fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.
4030. The method of claim 4029, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.
4031. The method of claim 4016, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.
4032. The method ofclaim 4031, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the foimation.
4033. The method ofclaim 4016, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.
4034. The method ofclaim 4016, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within at least the portion of the selected section to increase a H2 concenfration within the produced synthesis gas.
4035. The method of clahn 4016, wherein the synthesis gas generathig fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within at least the portion of the selected section to increase an energy content of the produced synthesis gas.
4036. The method of claim 4016, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate elecfricity.
4037. The method of claim 4016, further comprising generating elecfricity from the synthesis gas using a fuel cell.
4038. The method of claim 4016, further comprising generating electricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the formation.
4039. The method of claim 4016, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heat sources.
4040. The method ofclaim 4016, further comprising converting at least a portion of the produced synthesis gas to condensable hydrocarbons using a Fischer-Tropsch synthesis process.
4041. The method of claim 4016, further comprising converting at least a portion of the produced synthesis gas to methanol.
4042. The method of claim 4016, further comprising converting at least a portion of the produced synthesis gas to gasoline.
4043. The method ofclaim 4016, further comprising converting at least a portion of the synthesis gas to methane using a catalytic methanation process.
4044. The method of claim 4016, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
4045. The method ofclaim 4016, further comprising providing heat from three or more heat sources to at least a portion of the foπnation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a ttiangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
4046. A method for in situ production of synthesis gas from a relatively low permeability foimation containing heavy hydrocarbons, comprising:
heating a first portion of the formation to pyrolyze some hydrocarbons within the first portion; allowing the heat to fransfer from one or more heat sources to a selected section of the formation, pyrolyzing hydrocarbons within the selected section; producing fluid from the ffrst portion, wherein the fluid comprises an aqueous fluid and a hydrocarbon fluid; heating a second portion of the formation to a temperature sufficient to allow synthesis gas generation; introducing at least a portion of the aqueous fluid to the second section after the section reaches the temperature sufficient to allow synthesis gas generation; and producing synthesis gas from the foπnation.
4047. The method of claim 4046, wherein the temperature sufficient to allow synthesis gas generation ranges from approximately 400 °C to approximately 1200 °C.
4048. The method ofclaim 4046, further comprising separating ammonia within the aqueous phase from the aqueous phase prior to introduction of at least the portion of the aqueous fluid to the second section.
4049. The method ofclaim 4046, further comprising heating the second portion of the formation during introduction of at least the portion of the aqueous fluid to the second section to inhibit temperature decrease in the second section due to synthesis gas generation.
4050. The method of claim 4046, wherein heating the second portion of the formation comprises converting an oxidizing fluid into a portion of the second portion that is above a temperature sufficient to support oxidation of carbon within the portion with the oxidizing fluid, and reacting the oxidizing fluid with carbon in the portion to generate heat within the portion.
4051. The method of claim 4046, wherein heating the second portion of the foimation comprises diffusing an oxidizing fluid to reaction zones adjacent to wellbores within the formation, oxidizing carbon within the reaction zones to generate heat, and fransfening the heat to the second portion.
4052. The method of claim 4046, wherein heating the second portion of the formation comprises heating the second section by transfer of heat from one or more electrical heaters.
4053. The method ofclaim 4046, wherein heating the second portion of the formation comprises heating the second section with a flameless disfributed combustor.
4054. The method of claim 4046, wherein heating the second portion of the formation comprises injecting steam into at least the portion of the formation.
4055. The method ofclaim 4046, wherein at least the portion of the aqueous fluid comprises a liquid phase.
4056. The method of clahn 4046, wherein at least a portion of the aqueous fluid comprises a vapor phase.
4057. The method of claim 4046, further comprising adding carbon dioxide to at least the portion of aqueous fluid to inhibit production of carbon dioxide from carbon within the formation.
4058. The method ofclaim 4057, wherein a portion of the carbon dioxide comprises carbon dioxide removed from the formation.
4059. The method of claim 4046, further comprising adding hydrocarbons with carbon numbers less than 5 to at least the portion of the aqueous fluid to increase a H2 concentration within the produced synthesis gas.
4060. The method of claim 4046, further comprising adding hydrocarbons with carbon numbers less than 5 to at least the portion of the aqueous fluid to increase a H2 concenfration within the produced synthesis gas, wherein the hydrocarbons are obtained from the produced fluid.
4061. The method of claim 4046, further comprising adding hydrocarbons with carbon numbers greater than 4 to at least the portion of the aqueous fluid to increase energy content of the produced synthesis gas.
4062. The method of claim 4046, further comprising adding hydrocarbons with carbon numbers greater than 4 to at least the portion of the aqueous fluid to increase energy content of the produced synthesis gas, wherein the hydrocarbons are obtained from the produced fluid.
4063. The method of claim 4046, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.
4064. The method of claim 4046, further comprising generating elecfricity from the synthesis gas using a fuel cell.
4065. The method of claim 4046, further comprising generating elecfricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent portion of the foπnation.
4066. The method of claim 4046, further comprishig using a portion of the synthesis gas as a combustion fuel for the one or more heat sources.
4067. The method ofclaim 4046, further comprising converting at least a portion of the produced synthesis gas to condensable hydrocarbons using a Fischer-Tropsch synthesis process.
4068. The method ofclaim 4046, further comprising converting at least a portion of the produced synthesis gas to methanol.
4069. The method of claim 4046, further comprising converting at least a portion of the produced synthesis gas to gasoline.
4070. The method of claim 4046, further comprising converting at least a portion of the synthesis gas to methane using a catalytic methanation process.
4071. The method ofclaim 4046, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
4072. The method of claim 4046, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a ttiangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
4073. A method for in situ production of synthesis gas from a relatively low peπneability fonnation containing heavy hydrocarbons, comprising: heating a portion of the formation with one or more heat sources to raise a temperature within the portion to a temperature sufficient to allow synthesis gas generation; providing a synthesis gas generating fluid into the portion through at least one injection wellbore to generate synthesis gas from hydrocarbons and the synthesis gas generating fluid; and producing synthesis gas from at least one heat source in which is positioned a heat source of the one or more heat sources.
4074. The method of claim 4073, wherein the temperature sufficient to allow synthesis gas generation is within a range from about 400° C to about 1200 °C.
4075. The method ofclaim 4073, wherein heating the portion comprises heating the portion to a temperature within a range sufficient to pyrolyze hydrocarbons within the portion, raising the temperature within the portion at a rate of less than about 5 °C per day during pyrolyzation and removing a portion of pyrolyzed fluid from the formation.
4076. The method ofclaim 4073, further comprising removing fluid from the formation through at least the one injection wellbore prior to heating the selected section to the temperature sufficient to allow synthesis gas generation.
4077. The method of claim 4073, wherein the injection wellbore comprises a wellbore of a heat source in which is positioned a heat source of the one or more heat sources.
4078. The method ofclaim 4073, further comprising heating the selected portion during providing the synthesis gas generating fluid to inhibit temperature decrease in at least the portion of the selected section due to synthesis gas generation.
4079. The method of clahn 4073 , further comprising providing a portion of the heat needed to raise the temperature sufficient to allow synthesis gas generation by convecting an oxidizing fluid to hydrocarbons within the selected section to oxidize a portion of the hydrocarbons and generate heat.
4080. The method ofclaim 4073, further comprising confrolling the heating of the selected section and provision of the synthesis gas generating fluid to maintain a temperature within the selected section above the temperature sufficient to generate synthesis gas.
4081. The method of claim 4073, further comprishig: monitoring a composition of the produced synthesis gas; and confrolling heating of the selected section and provision of the synthesis gas generating fluid to maintain the composition of the produced synthesis gas within a desfred range.
4082. The method ofclaim 4073, wherein the synthesis gas generating fluid comprises liquid water.
4083. The method ofclaim 4073, wherein the synthesis gas generating fluid comprises steam.
4084. The method ofclaim 4073, wherein the synthesis gas generating fluid comprises steam to heat the selected section and to generate synthesis gas.
4085. The method ofclaim 4073, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.
4086. The method ofclaim 4085, wherein a portion of the carbon dioxide comprises carbon dioxide removed from the fonnation.
4087. The method ofclaim 4073, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.
4088. The method ofclaim 4087, wherein a portion of the carbon dioxide comprises carbon dioxide removed from the formation.
4089. The method ofclaim 4073, wherehi providing the synthesis gas generating fluid to the selected section comprises raising a water table of the formation to allow water to enter the selected section.
4090. The method ofclaim 4073, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons undergo a reaction within the selected section to increase a H2 concenfration within the produced synthesis gas.
4091. The method ofclaim 4073, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within the selected section to increase an energy content of the produced synthesis gas.
4092. The method of claim 4073, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electticity.
4093. The method ofclaim 4073, further comprising generating electticity from the synthesis gas using a fuel cell.
4094. The method ofclaim 4073, further comprising generating electticity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent portion of the formation.
4095. The method ofclaim 4073, further comprising using a portion of the synthesis gas as a combustion fuel for heating the formation.
4096. The method ofclaim 4073, further comprising converting at least a portion of the produced synthesis gas to condensable hydrocarbons using a Fischer-Tropsch synthesis process.
4097. The method ofclaim 4073, further comprising converting at least a portion of the produced synthesis gas to methanol.
4098. The method ofclaim 4073, further comprising converting at least a portion of the produced synthesis gas to gasoline.
4099. The method of claim 4073, further comprising converting at least a portion of the synthesis gas to methane using a catalytic methanation process.
4100. The method ofclaim 4073, wherein a temperature of at least the one heat source is maintained at a temperature of less than approximately 700 °C to produce a synthesis gas having a ratio of H2 to carbon monoxide of greater than about 2.
4101. The method of claim 4073 , wherehi a temperature of at least the one heat source is maintained at a temperature of greater than approximately 700 °C to produce a synthesis gas having a ratio of H2 to carbon monoxide of less than about 2.
4102. The method of claim 4073 , wherein a temperature of at least the one heat source is maintained at a temperature of approximately 700 °C to produce a synthesis gas having a ratio of H2 to carbon monoxide of approximately 2.
4103. The method ofclaim 4073, wherein a heat source of the one or more heat sources comprises an electrical heater.
4104. The method ofclaim 4073, wherein a heat source of the one or more heat sources comprises a natural distributed heater.
4105. The method ofclaim 4073, wherein a heat source of the one or more heat sources comprises a flameless disfributed combustor (FDC) heater, and wherein fluids are produced from the wellbore of the FDC heater through a conduit positioned within the wellbore.
4106. The method of claim 4073 , further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a friangular pattern.
4107. The method ofclaim 4073, further comprising providing heat from three or more heat sources to at least a portion of the foimation, wherein three or more of the heat sources are located in the foimation in a unit of heat sources, wherein the unit of heat sources comprises a ttiangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
4108. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation such that the heat from the one or more heat sources pyrolyzes at least a portion of the hydrocarbon containing material within the selected section of the formation; producing pyrolysis products from the formation; heating a first portion of a formation with one or more heat sources to a temperature sufficient to allow generation of synthesis gas; providing a ffrst synthesis gas generating fluid to the first portion to generate a first synthesis gas; removing a portion of the first synthesis gas from the formation; heating a second portion of a formation with one or more heat sources to a temperature sufficient to allow generation of synthesis gas having a H2 to CO ratio greater than a H2 to CO ratio of the ffrst synthesis gas; providing a second synthesis gas generating component to the second portion to generate a second synthesis gas; removing a portion of the second synthesis gas from the formation; and
blending a portion of the ffrst synthesis gas with a portion of the second synthesis gas to produce a blended synthesis gas having a selected H2 to CO ratio.
4109. The method of clahn 4108, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
4110. The method ofclaim 4108, wherein the first synthesis gas generating fluid and second synthesis gas generating fluid are the same component.
4111. The method of claim 4108, further comprising controlling the temperature in the first portion to confrol a composition of the first synthesis gas.
4112. The method of claim 4108, further comprising confrolling the temperature in the second portion to confrol a composition of the second synthesis gas.
4113. The method of claim 4108, wherein the selected ratio is confrolled to be approximately 2: 1 H2 to CO.
4114. The method of clahn 4108, wherein the selected ratio is confrolled to range from approximately 1.8:1 to approximately 2.2: 1 H2 to CO.
4115. The method ofclaim 4108, wherein the selected ratio is confrolled to be approximately 3:1 H2to CO.
4116. The method of clahn 4108, wherein the selected ratio is confrolled to range from approximately 2.8:1 to approximately 3.2:1 H2to CO.
4117. The method ofclaim 4108, further comprishig providing at least a portion of the produced blended synthesis gas to a condensable hydrocarbon synthesis process to produce condensable hydrocarbons.
4118. The method of claim 4117, wherein the condensable hydrocarbon synthesis process comprises a Fischer- Tropsch process.
4119. The method ofclaim 4118, further comprising cracking at least a portion of the condensable hydrocarbons to form middle distillates.
4120. The method ofclaim 4108, further comprising providing at least a portion of the produced blended synthesis gas to a catalytic methanation process to produce methane.
4121. The method of claim 4108, further comprising providing at least a portion of the produced blended synthesis gas to a methanol-synthesis process to produce methanol.
4122. The method ofclaim 4108, further comprising providing at least a portion of the produced blended synthesis gas to a gasoline-synthesis process to produce gasoline.
4123. The method of clahn 4108, wherein removing a portion of the second synthesis gas comprises withdrawing second synthesis gas through a production well, wherein a temperature of the production well adjacent to a second syntheses gas production zone is maintained at a substantially constant temperature configured to produce second synthesis gas having the H2 to CO ratio greater the first synthesis gas.
4124. The method of claim 4108, wherein the first synthesis gas producing fluid comprises C02 and wherein the temperature of the ffrst portion is at a temperature that will result in conversion of C02 and carbon from the ffrst portion to CO to generate a CO rich first synthesis gas.
4125. The method ofclaim 4108, wherein the second synthesis gas producing fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons react within the formation to increase a H2 concenfration within the produced second synthesis gas.
4126. The method ofclaim 4108, wherein blending a portion of the first synthesis gas with a portion of the second synthesis gas comprises producing an intermediate mixture having a H2 to CO mixture of less than the selected ratio, and subjecting the intermediate mixture to a shift reaction to reduce an amount of CO and increase an amount of H2 to produce the selected ratio of H2 to CO.
4127. The method of claim 4108, further comprising removing an excess of first synthesis gas from the first portion to have an excess of CO, subjecting the ffrst synthesis gas to a shift reaction to reduce an amount of CO and increase an amount of H2 before blending the first synthesis gas with the second synthesis gas.
4128. The method ofclaim 4108, further comprising removing the first synthesis gas from the foπnation under pressure, and passing removed first synthesis gas through a turbine to generate elecfricity.
4129. The method ofclaim 4108, further comprising removing the second synthesis gas from the formation under pressure, and passing removed second synthesis gas through a turbine to generate electticity.
4130. The method ofclaim 4108, further comprising generating electticity from the blended synthesis gas using a fuel cell.
4131. The method of claim 4108, further comprising generating elecfricity from the blended synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent portion of the formation.
4132. The method ofclaim 4108, further comprising using at least a portion of the blended synthesis gas as a combustion fuel for heating the formation.
4133. The method of clahn 4108, further comprising heating at least the portion of the selected section when providing the synthesis gas generating fluid to inhibit temperature decrease within the selected section during synthesis gas generation.
4134. The method ofclaim 4108, wherehi the temperature sufficient to allow synthesis gas generation is within a range from approxhnately 400 °C to approxhnately 1200 °C.
4135. The method ofclaim 4108, wherein heating the first a portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: heating zones adjacent to wellbores of one or more heat sources with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid; introducing the oxidizing fluid to the zones substantially by diffusion; allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and transfening heat from the zones to the selected section.
4136. The method of claim 4108, wherehi heating the second portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: heating zones adjacent to wellbores of one or more heat sources with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid; introducing the oxidizing fluid to the zones substantially by diffusion; allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and transfening heat from the zones to the selected section.
4137. The method ofclaim 4108, wherein heating the first portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: introducing an oxidizing fluid into the formation through a wellbore; ttansporting the oxidizing fluid substantially by convection into the first portion of the selected section, wherein the ffrst portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and reacting the oxidizing fluid within the first portion of the selected section to generate heat and raise the temperature of the first portion.
4138. The method ofclaim 4108, wherein heating the second portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: infroducing an oxidizing fluid into the foπnation through a wellbore;
ttansporting the oxidizing fluid substantially by convection into the second portion of the selected section, wherein the second portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and reacting the oxidizing fluid within the second portion of the selected section to generate heat and raise the temperature of the second portion.
4139. The method ofclaim 4108, wherein the one or more heat sources comprise one or more electrical heaters disposed in the formation.
4140. The method ofclaim 4108, wherein the one or more heat sources comprises one or more natural distributed combustors.
4141. The method ofclaim 4108, wherein the one or more heat sources comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4142. The method of claim 4108, wherein heating the ffrst portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a first synthesis gas generating fluid to the first portion of the selected section comprises introducing steam into the first portion.
4143. The method of claim 4108, wherein heating the second portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a second synthesis gas generating fluid to the second portion of the selected section comprises introducing steam into the second portion.
4144. The method of clahn 4108, further comprising controlling the heating of the ffrst portion of selected section and provision of the first synthesis gas generating fluid to maintain a temperature within the ffrst portion of the selected section above the temperature sufficient to generate synthesis gas.
4145. The method of claim 4108, further comprising confrolling the heating of the second portion of selected section and provision of the second synthesis gas generating fluid to maintain a temperature within the second portion of the selected section above the temperature sufficient to generate synthesis gas.
4146. The method ofclaim 4108, wherein the ffrst synthesis gas generating fluid comprises liquid water.
4147. The method ofclaim 4108, wherein the second synthesis gas generating fluid comprises liquid water.
4148. The method ofclaim 4108, wherein the first synthesis gas generating fluid comprises steam.
4149. The method ofclaim 4108, wherein the second synthesis gas generathig fluid comprises steam.
4150. The method ofclaim 4108, wherein the first synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.
4151. The method of claim 4150, wherein a portion of the carbon dioxide within the ffrst synthesis gas generating fluid comprises carbon dioxide removed from the foπnation.
4152. The method ofclaim 4108, wherein the second synthesis gas generathig fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.
4153. The method ofclaim 4152, wherein a portion of the carbon dioxide within the second synthesis gas generating fluid comprises carbon dioxide removed from the formation.
4154. The method ofclaim 4108, wherein the first synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.
4155. The method of clahn 4154, wherein a portion of the carbon dioxide within the first synthesis gas generating fluid comprises carbon dioxide removed from the foimation.
4156. The method ofclaim 4108, wherein the second synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the foimation to generate carbon monoxide.
4157. The method ofclaim 4156, wherein a portion of the carbon dioxide within the second synthesis gas generating fluid comprises carbon dioxide removed from the formation.
4158. The method ofclaim 4108, wherein providing the first synthesis gas generating fluid to the ffrst portion of the selected section comprises raising a water table of the formation to allow water to flow into the first portion of the selected section.
4159. The method ofclaim 4108, wherein providing the second synthesis gas generating fluid to the second portion of the selected section comprises raising a water table of the formation to allow water to flow into the second portion of the selected section.
4160. The method of claim 4108, wherein the first synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within the first portion of the selected section to increase a H2 concentration within the produced first synthesis gas.
4161. The method of clahn 4108, wherein the second synthesis gas generating fluid comprises water and hydrocarbons having carbon nmnbers less than 5, and wherein at least a portion of the hydrocarbons are subjected
to a reaction within the second portion of the selected section to increase a H2 concenfration within the produced second synthesis gas.
4162. The method ofclaim 4108, wherein the ffrst synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within the first portion of the selected section to increase an energy content of the produced first synthesis gas.
4163. The method ofclaim 4108, wherein the second synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within at least the second portion of the selected section to increase an energy content of the second produced synthesis gas.
4164. The method of claim 4108, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced blended synthesis gas through a turbine to generate electticity.
4165. The method of claim 4108, further comprising generating electricity from the blended synthesis gas using a fuel cell.
4166. The method ofclaim 4108, further comprising generating elecfricity from the blended synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the foimation.
4167. The method ofclaim 4108, further comprising using a portion of the blended synthesis gas as a combustion fuel for the one or more heat sources.
4168. The method of clahn 4108, further comprising using a portion of the ffrst synthesis gas as a combustion fuel for the one or more heat sources.
4169. The method of claim 4108, further comprising using a portion of the second synthesis gas as a combustion fuel for the one or more heat sources.
4170. The method ofclaim 4108, further comprising using a portion of the blended synthesis gas as a combustion fuel for the one or more heat sources.
4171. A method of freating a relatively low permeability foimation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation such that the heat from the one or more heat sources pyrolyzes at least some of the hydrocarbons within the selected section of the formation;
producing pyrolysis products from the formation; heating at least a portion of the selected section to a temperature sufficient to generate synthesis gas; confrolling a temperature of at least a portion of the selected section to generate synthesis gas having a selected H2 to CO ratio; providing a synthesis gas generating fluid to at least the portion of the selected section to generate synthesis gas; and producing a portion of the synthesis gas from the fonnation.
4172. The method ofclaim 4171, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
4173. The method ofclaim 4171, wherein the selected ratio is confrolled to be approxhnately 2: 1 H2 to CO.
4174. The method ofclaim 4171, wherein the selected ratio is confrolled to range from approximately 1.8: 1 to approximately 2.2:1 H2to CO.
4175. The method ofclaim 4171, wherein the selected ratio is controlled to be approximately 3:1 H2to CO.
4176. The method ofclaim 4171, wherein the selected ratio is confrolled to range from approximately 2.8:1 to approxhnately 3.2: 1 H2to CO.
177. The method of claim 4171, further comprising providing at least a portion of the produced synthesis gas to a condensable hydrocarbon synthesis process to produce condensable hydrocarbons.
4178. The method ofclaim 4177, wherein the condensable hydrocarbon synthesis process comprises a Fischer- Tropsch process.
4179. The method ofclaim 4178, further comprising cracking at least a portion of the condensable hydrocarbons to form middle distillates.
4180. The method ofclaim 4171, further comprishig providing at least a portion of the produced synthesis gas to a catalytic methanation process to produce methane.
4181. The method ofclaim 4171, further comprising providing at least a portion of the produced synthesis gas to a methanol-synthesis process to produce methanol.
4182. The method ofclaim 4171, further comprising providing at least a portion of the produced synthesis gas to a gasoline-synthesis process to produce gasoline.
4183. The method ofclaim 4171, further comprising heating at least-the portion of the selected section when providing the synthesis gas generating fluid to inhibit temperature decrease within the selected section during synthesis gas generation.
4184. The method ofclaim 4171, wherein the temperature sufficient to allow synthesis gas generation is within a range from approximately 400 °C to approximately 1200 °C.
4185. The method ofclaim 4171, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: heating zones adjacent to wellbores of one or more heat sources with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid; infroducing the oxidizing fluid to the zones substantially by diffusion; allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and transferring heat from the zones to the selected section.
4186. The method of claim 4171, wherehi heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: infroducing an oxidizing fluid into the formation through a wellbore; fransporting the oxidizing fluid substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and reacting the oxidizing fluid within the portion of the selected section to generate heat and raise the temperature of the portion.
4187. The method of claim 4171, wherein the one or more heat sources comprise one or more elecfrical heaters disposed in the formation.
4188. The method of claim 4171, wherein the one or more heat sources comprises one or more natural disfributed combustors.
4189. The method ofclaim 4171, wherein the one or more heat sources comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the foimation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4190. The method of clahn 4171, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a synthesis gas generating fluid to at least the portion of the selected section comprises infroducing steam into the portion.
4191. The method of claim 4171, further comprising confrolling the heating of at least the portion of selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.
4192. The method ofclaim 4171, wherein the synthesis gas generating fluid comprises liquid water.
4193. The method of claim 4171, wherein the synthesis gas generating fluid comprises steam.
4194. The method ofclaim 4171, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.
4195. The method ofclaim 4194, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the foimation.
4196. The method ofclaim 4171, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.
4197. The method ofclaim 4196, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.
4198. The method of claim 4171, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.
4199. The method ofclaim 4171, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within at least the portion of the selected section to increase a H2 concenfration within the produced synthesis gas.
4200. The method of clahn 4171 , wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within at least the portion of the selected section to increase an energy content of the produced synthesis gas.
4201. The method of claim 4171, further comprishig maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.
4202. The method of clahn 4171, further comprishig generating elecfricity from the synthesis gas using a fuel cell.
4203. The method ofclaim 4171, further comprismg generating electticity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the formation.
4204. The method ofclaim 4171, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heat sources.
4205. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation such that the heat from the one or more heat sources pyrolyzes at least some of the hydrocarbons within the selected section of the formation; producing pyrolysis products from the formation; heating at least a portion of the selected section to a temperature sufficient to generate synthesis gas; conttoUing a temperature in or proximate to a synthesis gas production well to generate synthesis gas having a selected H2 to CO ratio; providing a synthesis gas generating fluid to at least the portion of the selected section to generate synthesis gas; and producing synthesis gas from the formation.
4206. The method of claim 4205, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
4207. The method of claim 4205, wherein the selected ratio is confrolled to be approximately 2:1 H2 to CO.
4208. The method of claim 4205, wherein the selected ratio is controlled to range from approximately 1.8: 1 to approximately 2.2:1 H2to CO.
4209. The method of claim 4205, wherein the selected ratio is confrolled to be approximately 3 : 1 H2 to CO.
4210. The method ofclaim 4205, wherein the selected ratio is confrolled to range from approximately 2.8:1 to approximately 3.2:1 H2 to CO.
4211. The method of clahn 4205, further comprising providing at least a portion of the produced synthesis gas to a condensable hydrocarbon synthesis process to produce condensable hydrocarbons.
4212. The method ofclaim 4211, wherein the condensable hydrocarbon synthesis process comprises a Fischer- Tropsch process.
4213. The method ofclaim 4212, further comprising cracking at least a portion of the condensable hydrocarbons to form middle distillates.
4214. The method ofclaim 4205, further comprising providing at least a portion of the produced synthesis gas to a catalytic methanation process to produce methane.
4215. The method ofclaim 4205, further comprising providing at least a portion of the produced synthesis gas to a methanol-synthesis process to produce methanol.
4216. The method ofclaim 4205, further comprising providing at least a portion of the produced synthesis gas to a gasoline-synthesis process to produce gasoline.
4217. The method ofclaim 4205, further comprising heating at least the portion of the selected section when providing the synthesis gas generating fluid to inhibit temperature decrease within the selected section during synthesis gas generation.
4218. The method ofclaim 4205, wherein the temperature sufficient to allow synthesis gas generation is within a range from approximately 400 °C to approximately 1200 °C.
4219. The method ofclaim 4205, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: heating zones adjacent to wellbores of one or more heat sources with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid; introducing the oxidizing fluid to the zones substantially by diffusion; allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and fransfening heat from the zones to the selected section.
4220. The method of claim 4205, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: introducing an oxidizing fluid into the formation through a wellbore; transporting the oxidizing fluid substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and reacting the oxidizing fluid within the portion of the selected section to generate heat and raise the temperature of the portion.
4221. The method of claim 4205, wherein the one or more heat sources comprise one or more electrical heaters disposed in the foπnation.
4222. The method ofclaim 4205, wherein the one or more heat sources comprises one or more natural distributed combustors.
4223. The method ofclaim 4205, wherein the one or more heat sources comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4224. The method ofclaim 4205, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a synthesis gas generating fluid to at least the portion of the selected section comprises introducing steam into the portion.
4225. The method ofclaim 4205, further comprishig confrolling the heating of at least the portion of selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.
4226. The method of claim 4205, wherein the synthesis gas generating fluid comprises liquid water.
4227. The method of clahn 4205, wherein the synthesis gas generating fluid comprises steam.
4228. The method ofclaim 4205, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.
4229. The method of claim 4228, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.
4230. The method ofclaim 4205, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.
4231. The method of claim 4230, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.
4232. The method of claim 4205, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.
4233. The method ofclaim 4205, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within at least the portion of the selected section to increase a H2 concentration within the produced synthesis gas.
4234. The method ofclaim 4205, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within at least the portion of the selected section to increase an energy content of the produced synthesis gas.
4235. The method ofclaim 4205, further comprising maintaining a pressure withhi the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.
4236. The method ofclaim 4205, further comprising generating elecfricity from the synthesis gas using a fuel cell.
4237. The method ofclaim 4205, further comprising generating elecfricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the formation.
4238. The method ofclaim 4205, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heat sources.
4239. A method of treating a relatively low permeability formation containing heavy, hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation such that the heat from the one or more heat sources pyrolyzes at least some of the hydrocarbons within the selected section of the formation; producing pyrolysis products from the formation; heating at least a portion of the selected section to a temperature sufficient to generate synthesis gas; confrolling a temperature of at least a portion of the selected section to generate synthesis gas having a H2 to CO ratio different than a selected H2 to CO ratio; providing a synthesis gas generating fluid to at least the portion of the selected section to generate synthesis gas; and producing synthesis gas from the foimation; providing at least a portion of the produced synthesis gas to a shift process wherein an amount of carbon monoxide is converted to carbon dioxide; separating at least a portion of the carbon dioxide to obtain a gas having a selected H2 to CO ratio.
4240. The method of clahn 4239, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
4241. The method of claim 4239, wherein the selected ratio is confrolled to be approximately 2: 1 H2 to CO.
4242. The method ofclaim 4239, wherein the selected ratio is controlled to range from approximately 1.8:1 to 2.2:1 H2 to CO.
4243. The method of claim 4239, wherein the selected ratio is controlled to be approximately 3 : 1 H2 to CO.
4244. The method ofclaim 4239, wherein the selected ratio is confrolled to range from approximately 2.8: 1 to 3.2:1 H2 to CO.
4245. The method ofclaim 4239, further comprising providing at least a portion of the produced synthesis gas to a condensable hydrocarbon synthesis process to produce condensable hydrocarbons.
4246. The method ofclaim 4245, wherein the condensable hydrocarbon synthesis process comprises a Fischer- Tropsch process.
4247. The method of claim 4246, further comprising cracking at least a portion of the condensable hydrocarbons to form middle distillates.
4248. The method ofclaim 4239, further comprising providing at least a portion of the produced synthesis gas to a catalytic methanation process to produce methane.
4249. The method of claim 4239, further comprising providing at least a portion of the produced synthesis gas to a methanol-synthesis process to produce methanol.
4250. The method of claim 4239, further comprising providing at least a portion of the produced synthesis gas to a gasoline-synthesis process to produce gasoline.
4251. The method of claim 4239, further comprising heating at least the portion of the selected section when providing the synthesis gas generating fluid to inhibit temperature decrease within the selected section during synthesis gas generation.
4252. The method ofclaim 4239, wherein the temperature sufficient to allow synthesis gas generation is within a range from approximately 400 °C to approximately 1200 °C.
4253. The method ofclaim 4239, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: heating zones adjacent to wellbores of one or more heat sources with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid; introducing the oxidizing fluid to the zones substantially by diffusion; allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and fransfening heat from the zones to the selected section.
4254. The method of claim 4239, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises: infroducing an oxidizing fluid into the formation through a wellbore; transporting the oxidizhig fluid substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and reacting the oxidizing fluid within the portion of the selected section to generate heat and raise the temperature of the portion.
4255. The method of claim 4239, wherein the one or more heat sources comprise one or more electrical heaters disposed in the formation.
4256. The method ofclaim 4239, wherein the one or more heat sources comprises one or more natural distributed combustors.
4257. The method ofclaim 4239, wherein the one or more heat sources comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4258. The method of clahn 4239, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a synthesis gas generating fluid to at least the portion of the selected section comprises infroducing steam into the portion.
4259. The method of claim 4239, further comprising confrolling the heating of at least the portion of selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.
4260. The method of claim 4239, wherein the synthesis gas generating fluid comprises liquid water.
4261. The method ofclaim 4239, wherein the synthesis gas generating fluid comprises steam.
4262. The method of claim 4239, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.
4263. The method of claim 4262, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the foimation.
4264. The method ofclaim 4239, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.
4265. The method ofclaim 4264, wherein a portion of the carbon dioxide within the synthesis gas generathig fluid comprises carbon dioxide removed from the formation.
4266. The method of claim 4239, wherehi providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.
4267. The method of claim 4239, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within at least the portion of the selected section to increase a H2 concenfration within the produced synthesis gas.
4268. The method ofclaim 4239, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within at least the portion of the selected section to increase an energy content of the produced synthesis gas.
4269. The method ofclaim 4239, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate elecfricity.
4270. The method ofclaim 4239, further comprising generating elecfricity from the synthesis gas using a fuel cell.
4271. The method ofclaim 4239, further comprising generating elecfricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the formation.
4272. The method of clahn 4239, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heat sources.
4273. A method of forming a spent portion of formation within a relatively low permeability formation containing heavy hydrocarbons, comprising:
heating a first portion of the formation to pyrolyze hydrocarbons within the first portion; and cooling the first portion.
4274. The method of claim 4273, wherein heating the first portion comprises transfening heat to the ffrst portion from one or more elecfrical heaters.
4275. The method ofclaim 4273, wherein heating the first portion comprises fransfening heat to the first portion from one or more natural disfributed combustors.
4276. The method ofclaim 4273, wherein heating the first portion comprises transfening heat to the first portion from one or more flameless disfributed combustors.
4277. The method ofclaim 4273, wherein heating the first portion comprises fransfening heat to the first portion from heat ttansfer fluid flowing within one or more wellbores within the formation.
4278. The method ofclaim 4277, wherein the heat transfer fluid comprises steam.
4279. The method of claim 4277, wherein the heat fransfer fluid comprises combustion products from a burner.
4280. The method of claim 4273, wherein heating the ffrst portion comprises transfening heat to the ffrst portion from at least two heater wells positioned within the formation, wherein the at least two heater wells are placed in a substantially regular pattern, wherein the substantially regular pattern comprises repetition of a base heater unit, and wherein the base heater unit is formed of a number of heater wells.
4281. The method of claim 4280, wherein a spacing between a pair of adjacent heater wells is within a range from about 6 m to about 15 m.
4282. The method ofclaim 4280, further comprising removing fluid from the formation through one or more production wells.
4283. The method of claim 4282, wherein the one or more production wells are located in a pattern, and wherehi the one or more production wells are positioned substantially at centers of base heater units.
4284. The method ofclaim 4280, wherein the heater unit comprises three heater wells positioned substantially at apexes of an equilateral triangle.
4285. The method ofclaim 4280, wherein the heater unit comprises four heater wells positioned substantially at apexes of a rectangle.
4286. The method of claim 4280, wherein the heater unit comprises five heater wells positioned substantially at apexes of a regular pentagon.
4287. The method ofclaim 4280, wherein the heater unit comprises six heater wells positioned substantially at apexes of a regular hexagon.
4288. The method ofclaim 4273, further comprising infroducing water to the first portion to cool the formation.
4289. The method of claim 4273, further comprising removmg steam from the formation.
4290. The method ofclaim 4289, further comprising using a portion of the removed steam to heat a second portion of the formation.
4291. The method ofclaim 4273, further comprising removing pyrolyzation products from the formation.
4292. The method of claim 4273, further comprising generating synthesis gas within the portion by introducing a synthesis gas generating fluid into the portion, and removing synthesis gas from the foimation.
4293. The method of claim 4273, further comprising heating a second section of the formation to pyrolyze hydrocarbons within the second portion, removing pyrolyzation fluid from the second portion, and storing a portion of the removed pyrolyzation fluid within the first portion.
4294. The method ofclaim 4293, wherein the portion of the removed pyrolyzation fluid is stored within the first portion when surface facilities that process the removed pyrolyzation fluid are not able to process the portion of the removed pyrolyzation fluid.
4295. The method ofclaim 4293, further comprising heating the first portion to facilitate removal of the stored pyrolyzation fluid from the ffrst portion.
4296. The method of claim 4273, further comprising generating synthesis gas within a second portion of the formation, removing synthesis gas from the second portion, and storing a portion of the removed synthesis gas within the ffrst portion.
4297. The method ofclaim 4296, wherein the portion of the removed synthesis gas from the second portion is stored within the first portion when surface facilities that process the removed synthesis gas are not able to process the portion of the removed synthesis gas.
4298. The method ofclaim 4296, further comprising heating the first portion to facilitate removal of the stored synthesis gas from the first portion.
4299. The method of claim 4273, further comprising removing at least a portion of hydrocarbon containing material in the first portion and, further comprising using at least a portion of the hydrocarbon containing material removed from the foπnation in a metallurgical application.
4300. The method ofclaim 4299, wherein the metallurgical application comprises steel manufacturing.
4301. A method of sequestering carbon dioxide within a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a portion of the formation; allowing the portion to cool; and storing carbon dioxide within the portion.
4302. The method ofclaim 4301, further comprising raising a water level within the portion to inhibit migration of the carbon dioxide from the portion.
4303. The method ofclaim 4301, further comprising heathig the portion to release carbon dioxide, and removing carbon dioxide from the portion.
4304. The method ofclaim 4301, further comprising pyrolyzing hydrocarbons within the portion during heating of the portion, and removing pyrolyzation product from the formation.
4305. The method ofclaim 4301, further comprising producing synthesis gas from the portion during the heating of the portion, and removing synthesis gas from the foπnation.
4306. The method ofclaim 4301, wherehi heating the portion comprises: heating hydrocarbon containing material adjacent to one or more wellbores to a temperature sufficient to support oxidation of the hydrocarbon containing material with an oxidizing fluid; introducing the oxidizing fluid to hydrocarbon containing material adjacent to the one or more wellbores to oxidize the hydrocarbons and produce heat; and conveying produced heat to the portion.
4307. The method ofclaim 4306, wherein heating hydrocarbon containing material adjacent to the one or more wellbores comprises electtically heating the hydrocarbon containing material.
4308. The method of claim 4306, wherehi the temperature sufficient to support oxidation is in a range from approximately 200 °C to approximately 1200 °C.
4309. The method ofclaim 4301, wherehi heating the portion comprises circulating heat transfer fluid through one or more heating wells within the foπnation.
4310. The method of claim 4309, wherein the heat transfer fluid comprises combustion products from a burner.
4311. The method of claim 4309, wherein the heat fransfer fluid comprises steam.
4312. The method ofclaim 4301, further comprising removing fluid from the formation during heating of the foimation, and combusting a portion of the removed fluid to generate heat to heat the formation.
4313. The method ofclaim 4301, further comprising using at least a portion of the carbon dioxide for hydrocarbon bed demethanation prior to storing the carbon dioxide within the portion.
4314. The method ofclaim 4301, further comprising using a portion of the carbon dioxide for enhanced oil recovery prior to storing the carbon dioxide within the portion.
4315. The method of claim 4301 , wherein at least a portion of the carbon dioxide comprises carbon dioxide generated in a fuel cell.
4316. The method ofclaim 4301, wherein at least a portion of the carbon dioxide comprises carbon dioxide formed as a combustion product.
4317. The method of claim 4301, further comprising allowing the portion to cool by infroducing water to the portion; and removing the water from the foimation as steam.
4318. The method of claim 4317, further comprishig using the steam as a heat transfer fluid to heat a second portion of the formation.
4319. The method ofclaim 4301, wherein storing carbon dioxide in the portion comprises adsorbing carbon dioxide to hydrocarbon containing material within the formation.
4320. The method ofclaim 4301, wherein storing carbon dioxide comprises passing a first fluid sfream comprising the carbon dioxide and other fluid through the portion; adsorbing carbon dioxide onto hydrocarbon containing material withhi the formation; and removing a second fluid stream from the foπnation, wherein a concenfration of the other fluid in the second fluid stream is greater than concentration of other fluid in the first stteam due to the absence of the adsorbed carbon dioxide in the second stteam.
4321. The method ofclaim 4301, wherein an amount of carbon dioxide stored within the portion is equal to or greater than an amount of carbon dioxide generated within the portion and removed from the foπnation during heating of the portion.
4322. The method ofclaim 4301, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherein the unit of heat sources comprises a triangular pattern.
4323. The method ofclaim 4301, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
4324. A method of in situ sequestration of carbon dioxide within a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a first portion of the formation; allowing the heat to fransfer from one or more sources to a selected section of the formation such that the heat from the one or more heat sources pyrolyzes at least some of the hydrocarbons within the selected section of the formation; producing pyrolyzation fluids, wherehi the pyrolyzation fluids comprise carbon dioxide; and storing an amount of carbon dioxide in the formation, wherein the amount of stored carbon dioxide is equal to or greater than an amount of carbon dioxide within the pyrolyzation fluids.
4325. The method of claim 4324, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
4326. The method of claim 4324, wherein the carbon dioxide is stored within a spent portion of the foimation.
4327. The method ofclaim 4324, wherein a portion of the carbon dioxide stored within the formation is carbon dioxide separated from the pyrolyzation fluids.
4328. The method ofclaim 4324, further comprising separating a portion of carbon dioxide from the pyrolyzation fluids, and using the carbon dioxide as a flooding agent in enhanced oil recovery.
4329. The method of claim 4324, further comprising separating a portion of carbon dioxide from the pyrolyzation fluids, and using the carbon dioxide as a synthesis gas generating fluid for the generation of synthesis gas from a section of the formation that is heated to a temperature sufficient to generate synthesis gas upon introduction of the synthesis gas generating fluid.
4330. The method ofclaim 4324, further comprising separating a portion of carbon dioxide from the pyrolyzation fluids, and using the carbon dioxide to displace hydrocarbon bed methane.
4331. The method ofclaim 4330, wherein the hydrocarbon bed is a deep hydrocarbon bed located over 760 m below ground surface.
4332. The method ofclaim 4330, further comprising adsorbing a portion of the carbon dioxide within the hydrocarbon bed.
4333. The method ofclaim 4324, further comprising using at least a portion of the pyrolyzation fluids as a feed stream for a fuel cell.
4334. The method ofclaim 4333, wherein the fuel cell generates carbon dioxide, and further comprising storing an amount of carbon dioxide equal to or greater than an amount of carbon dioxide generated by the fuel cell within the formation.
4335. The method ofclaim 4324, wherein a spent portion of the formation comprises hydrocarbon containing material within a section of the formation that has been heated and from which condensable hydrocarbons have been produced, and wherein the spent portion of the formation is at a temperature at which carbon dioxide adsorbs onto the hydrocarbon containing material.
4336. The method of claim 4324, further comprising raising a water level within the spent portion to inhibit migration of the carbon dioxide from the portion.
4337. The method ofclaim 4324, wherein producing fluids from the formation comprises removing pyrolyzation products from the formation.
4338. The method ofclaim 4324, wherehi producing fluids from the formation comprises heating the selected section to a temperature sufficient to generate synthesis gas; introducing a synthesis gas generating fluid into the selected section; and removing synthesis gas from the formation.
4339. The method ofclaim 4338, wherein the temperature sufficient to generate synthesis gas ranges from about 400 °C to about 1200 °C.
4340. The method ofclaim 4338, wherein heating the selected section comprises infroducing an oxidizing fluid into the selected section, reacting the oxidizing fluid within the selected section to heat the selected section.
4341. The method ofclaim 4338, wherein heating the selected section comprises: heating hydrocarbon containing material adjacent to one or more wellbores to a temperature sufficient to support oxidation of the hydrocarbon containing material with an oxidant; infroducing the oxidant to hydrocarbon containing material adjacent to the one or more wellbores to oxidize the hydrocarbons and produce heat; and conveying produced heat to the portion.
4342. The method ofclaim 4324, wherein the one or more heat sources comprise elecfrical heaters.
4343. The method ofclaim 4324, wherein the one or more heat sources comprise flameless distributed combustors.
4344. The method ofclaim 4343, wherein a portion of fuel for the one or more flameless disfributed combustors is obtained from the foπnation.
4345. The method ofclaim 4324, wherein the one or more heat sources comprise heater wells in the formation through which heat transfer fluid is circulated.
4346. The method of claim 4345, wherein the heat fransfer fluid comprises combustion products.
4347. The method of claim 4345, wherein the heat fransfer fluid comprises steam.
4348. The method of claim 4324, wherein condensable hydrocarbons are produced under pressure, and further comprising generating elecfricity by passing a portion of the produced fluids through a turbine.
4349. The method ofclaim 4324, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, and wherehi the unit of heat sources comprises a ttiangular pattern.
4350. The method of claim 4324, further comprising providing heat from three or more heat sources to at least a portion of the formation, wherein three or more of the heat sources are located in the formation in a unit of heat sources, wherein the unit of heat sources comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
4351. A method for in situ production of energy from a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation such that the heat from the one or more heat sources pyrolyzes at least a portion of the hydrocarbons within the selected section of the formation; producing pyrolysis products from the formation; providing at least a portion of the pyrolysis products to a reformer to generate synthesis gas; producing the synthesis gas from the reformer; providing at least a portion of the produced synthesis gas to a fuel cell to produce electricity, wherein the fuel cell produces a carbon dioxide containing exit sfream; and
storing at least a portion of the carbon dioxide in the carbon dioxide containing exit sfream in a subsurface formation.
4352. The method ofclaim 4351, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the fonnation.
4353. The method ofclaim 4351, wherein at least a portion of the pyrolysis products are used as fuel in the reformer.
4354. The method ofclaim 4351, wherein the synthesis gas comprises substantially H2.
4355. The method of claim 4351, wherein the subsurface formation is a spent portion of the foimation.
4356. The method of clahn 4351, wherein the subsurface formation is an oil reservoir.
4357. The method ofclaim 4356, wherein at least a portion of the carbon dioxide is used as a drive fluid for enhanced oil recovery in the oil reservofr.
4358. The method of claim 4351, wherein the subsurface formation is a hydrocarbon formation.
4359. The method of claim 4358, wherein at least a portion of the carbon dioxide is used to produce methane from the hydrocarbon foimation.
4360. The method of claim 4358, wherein the hydrocarbon formation is located over about 760 m below ground surface.
4361. The method ofclaim 4359, further comprising sequestering at least a portion of the carbon dioxide within the hydrocarbon formation.
4362. The method ofclaim 4351, wherein the reformer produces a reformer carbon dioxide containing exit stream.
4363. The method ofclaim 4362, further comprising storing at least a portion of the carbon dioxide in the reformer carbon dioxide containing exit sfream in the hydrocarbon foπnation.
4364. The method ofclaim 4351, wherein the subsurface foimation is a spent portion of the fonnation.
4365. The method ofclaim 4351, wherein the subsurface formation is an oil reservofr.
4366. The method ofclaim 4365, wherein at least a portion of the carbon dioxide in the reformer carbon dioxide containing exit sfream is used as a drive fluid for enhanced oil recovery in the oil reservofr.
4367. The method ofclaim 4351, wherein the subsurface foπnation is a coal formation.
4368. The method ofclaim 4367, wherein at least a portion of the carbon dioxide in the reformer carbon dioxide containing exit sfream is used to produce methane from the coal formation.
4369. The method ofclaim 4367, wherein the coal formation is located over about 760 m below ground surface.
4370. The method of claim 4368, further comprising sequestering at least a portion of the carbon dioxide in the reformer carbon dioxide containing exit sfream within the coal formation.
4371. The method of claim 4351, wherein the fuel cell is a molten carbonate fuel cell.
4372. The method ofclaim 4351, wherein the fuel cell is a solid oxide fuel cell.
4373. The method ofclaim 4351, further comprising using a portion of the produced elecfricity to power electrical heaters within the formation.
4374. The method ofclaim 4351, further comprising using a portion of the produced pyrolysis products as a feed sfream for the fuel cell.
4375. The method ofclaim 4351, wherein the one or more heat sources comprise one or more electrical heaters disposed in the formation.
4376. The method ofclaim 4351, wherein the one or more heat sources comprise one or more flameless distributed combustors disposed in the foimation.
4377. The method ofclaim 4376, wherein a portion of fuel for the flameless distributed combustors is obtained from the formation.
4378. The method ofclaim 4351, wherein the one or more heat sources comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the foimation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4379. The method of claim 4351, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heat sources.
4380. A method for producing ammonia using a relatively low penneability formation containing heavy hydrocarbons, comprising: separating afr to produce an 02 rich sfream and a N2 rich sfream; heating a selected section of the formation to a temperature sufficient to support reaction of hydrocarbon containing material in the formation to form synthesis gas; providing synthesis gas generating fluid and at least a portion of the 02 rich sfream to the selected section; allowing the synthesis gas generating fluid and 02 in the 02 rich sfream to react with at least a portion of the hydrocarbon containing material in the formation to generate synthesis gas; producing synthesis gas from the formation, wherein the synthesis gas comprises H2 and CO; providing at least a portion of the H2 in the synthesis gas to an ammonia synthesis process; providing N2 to the ammonia synthesis process; and using the ammonia synthesis process to generate ammonia.
4381. The method of claim 4380, wherein the ratio of the H2 to N2 provided to the ammonia synthesis process is approximately 3:1.
4382. The method ofclaim 4380, wherein the ratio of the H2 to N2 provided to the ammonia synthesis process ranges from approximately 2.8:1 to approxhnately 3.2:1.
4383. The method ofclaim 4380, wherein the temperature sufficient to support reaction of hydrocarbon containing material in the formation to form synthesis gas ranges from approximately 400 °C to approximately 1200 °C.
4384. The method of claim 4380, further comprising separating at least a portion of carbon dioxide in the synthesis gas from at least a portion of the synthesis gas.
4385. The method ofclaim 4384, wherein the carbon dioxide is separated from the synthesis gas by an amine separator.
4386. The method ofclaim 4385, further comprising providing at least a portion of the carbon dioxide to a urea synthesis process to produce urea.
4387. The method ofclaim 4380, wherein at least a portion of the N2 sfream is used to condense hydrocarbons with 4 or more carbon atoms from a pyrolyzation fluid.
4388. The method ofclaim 4380, wherein at least a portion of the N2 rich sfream is provided to the ammonia synthesis process.
4389. The method ofclaim 4380, wherein the afr is separated by cryogenic distillation.
4390. The method ofclaim 4380, wherein the ah is separated by membrane separation.
4391. The method of clahn 4380, wherein fluids produced during pyrolysis of a relatively low peπneability formation containing heavy hydrocarbons comprise aimnonia and, further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.
4392. The method ofclaim 4380, wherein fluids produced during pyrolysis of a hydrocarbon formation are hydrofreated and at least some ammonia is produced during hydrofreating, and, further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.
4393. The method of claim 4380, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea.
4394. The method of claim 4380, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and, further comprising providing carbon dioxide from the foπnation to the urea synthesis process.
4395. The method ofclaim 4380, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and, further comprising shifting at least a portion of the carbon monoxide to carbon dioxide in a shift process, and further comprising providing at least a portion of the carbon dioxide from the shift process to the urea synthesis process.
4396. The method of claim 4380, wherein heating the selected section of the formation to a temperature to support reaction of hydrocarbon containing material in the formation to form synthesis gas comprises: heating zones adjacent to wellbores of one or more heat sources with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with 02 in the 02rich sfream; infroducing the 02to the zones substantially by diffusion; allowing 02 in the 02 rich sfream to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and fransfening heat from the zones to the selected section.
4397. The method of claim 4396, wherein temperatures sufficient to support reaction of hydrocarbon containing material within the zones with 02 range from approximately 200 °C to approximately 1200 °C.
4398. The method ofclaim 4396, wherein the one or more heat sources comprises one or more electrical heaters disposed in the formation.
4399. The method ofclaim 4396, wherein the one or more heat sources comprises one or more natural disfributed combustors.
4400. The method ofclaim 4396, wherein the one or more heat sources comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and ftuther comprising heating the conduit by flowing a hot fluid through the conduit.
4401. The method ofclaim 4396, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heat sources.
4402. The method ofclaim 4380, wherein heating the selected section of the formation to a temperature to support reaction of hydrocarbon containing material in the formation to form synthesis gas comprises: infroducing the 02 rich stream into the foimation through a weUbore; fransporting 02 in the 02 rich stteam substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with 02 in the 02 rich stream; and reacting the 02 within the portion of the selected section to generate heat and raise the temperature of the portion.
4403. The method of claim 4403 , wherein the temperature sufficient to support an oxidation reaction with 02 ranges from approximately 200 °C to approximately 1200 °C.
4404. The method of clahn 4403, wherein the one or more heat sources comprises one or more electrical heaters disposed in the foimation.
4405. The method ofclaim 4403, wherein the one or more heat sources comprises one or more natural distributed combustors.
4406. The method of claim 4403, wherein the one or more heat sources comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4407. The method ofclaim 4403, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heat sources.
4408. The method ofclaim 4380, further comprising controlling the heating of at least the portion of the selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.
4409. The method of claim 4380, wherein the synthesis gas generating fluid comprises liquid water.
4410. The method ofclaim 4380, wherein the synthesis gas generating fluid comprises steam.
4411. The method of claim 4380, wherein the synthesis gas generating fluid comprises water and carbon dioxide wherehi the carbon dioxide inhibits production of carbon dioxide from the selected section.
4412. The method ofclaim 4411, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the foimation.
4413. The method ofclaim 4380, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.
4414. The method ofclaim 4413, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.
4415. The method of claim 4380, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.
4416. A method for producing ammonia using a relatively low permeability formation containing heavy hydrocarbons, comprising: generating a ffrst ammonia feed stteam from a first portion of the formation; generating a second ammonia feed sfream from a second portion of the formation, wherein the second ammonia feed sfream has a H2 to N2 ratio greater than a H2 to N2 ratio of the first ammonia feed sfream; blending at least a portion of the first ammonia feed sfream with at least a portion of the second ammonia feed sfream to produce a blended ammonia feed stream having a selected H2 to N2 ratio; providing the blended ammonia feed stteam to an ammonia synthesis process; and using the ammonia synthesis process to generate ammonia.
4417. The method of claim 4416, wherein the selected ratio is approximately 3:1.
4418. The method ofclaim 4416, wherein the selected ratio ranges from approximately 2.8:1 to approximately 3.2:1.
4419. The method ofclaim 4416, further comprising separating at least a portion of carbon dioxide in the first ammonia feed stream from at least a portion of the ffrst ammonia feed sfream.
4420. The method ofclaim 4419, wherein the carbon dioxide is separated from the ffrst ammonia feed sfream by an amine separator.
4421. The method of clahn 4420, further comprising providing at least a portion of the carbon dioxide to a urea synthesis process.
4422. The method ofclaim 4416, further comprising separating at least a portion of carbon dioxide in the blended ammonia feed sfream from at least a portion of the blended ammonia feed stteam.
4423. The method ofclaim 4422, wherein the carbon dioxide is separated from the blended ammonia feed stream by an amine separator.
4424. The method of claim 4423 , further comprising providing at least a portion of the carbon dioxide to a urea synthesis process
4425. The method ofclaim 4416, further comprising separating at least a portion of carbon dioxide in the second ammonia feed sfream from at least a portion of the second ammonia feed stream.
4426. The method of claim 4425, wherehi the carbon dioxide is separated from the second ammonia feed sfream by an amine separator.
4427. The method ofclaim 4426, further comprising providing at least a portion of the carbon dioxide to a urea synthesis process.
4428. The method of claim 4416, wherein fluids produced during pyrolysis of a relatively low permeability foimation containing heavy hydrocarbons comprise ammonia and, further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.
4429. The method of claim 4416, wherein fluids produced during pyrolysis of a hydrocarbon foimation are hydrofreated and at least some ammonia is produced during hydrotreating, and further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.
4430. The method ofclaim 4416, further comprising providing at least a portion of the aimnonia to a urea synthesis process to produce urea.
4431. The method of claim 4416, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and, further comprising providing carbon dioxide from the formation to the urea synthesis process.
4432. The method ofclaim 4416, further comprishig providing at least a portion of the ammonia to a urea synthesis process to produce urea and further comprising shifting at least a portion of carbon monoxide in the blended ammonia feed stream to carbon dioxide in a shift process, and further comprising providing at least a portion of the carbon dioxide from the shift process to the urea synthesis process.
4433. A method for producing ammonia using a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a selected section of the formation to a temperature sufficient to support reaction of hydrocarbon containing material in the formation to form synthesis gas; providing a synthesis gas generating fluid and an 02 rich stream to the selected section, wherein the amount of N2 in the 02 rich sfream is sufficient to generate synthesis gas having a selected ratio of H2 to N2; allowing the synthesis gas generating fluid and 02 in the 02 rich sfream to react with at least a portion of the hydrocarbon containing material in the foπnation to generate synthesis gas having a selected ratio of H2 to N2; producing the synthesis gas from the fonnation; providing at least a portion of the H2 and N2 in the synthesis gas to an ammonia synthesis process; using the ammonia synthesis process to generate ammonia.
4434. The method ofclaim 4433, further comprising confrolling a temperature of at least a portion of the selected section to generate synthesis gas having the selected H2 to N2 ratio.
4435. The method of clahn 4433, wherein the selected ratio is approximately 3:1.
4436. The method ofclaim 4433, wherein the selected ratio ranges from approximately 2.8:1 to 3.2:1.
4437. The method ofclaim 4433, wherein the temperature sufficient to support reaction of hydrocarbon containing material in the formation to form synthesis gas ranges from approxhnately 400 °C to approximately 1200 °C.
4438. The method ofclaim 4433, wherein the 02 stream and N2 sfream are obtained by cryogenic separation of afr.
4439. The method ofclaim 4433, wherein the 02 stream and N2 stream are obtained by membrane separation of afr.
4440. The method ofclaim 4433, further comprising separating at least a portion of carbon dioxide in the synthesis gas from at least a portion of the synthesis gas.
4441. The method ofclaim 4440, wherein the carbon dioxide is separated from the synthesis gas by an amine separator.
4442. The method of clahn 4441, further comprising providing at least a portion of the carbon dioxide to a urea synthesis process.
4443. The method of clahn 4433 , wherein fluids produced during pyrolysis of a relatively low permeability foπnation containing heavy hydrocarbons comprise ammonia and, further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.
4444. The method of claim 4433 , wherein fluids produced during pyrolysis of a hydrocarbon formation are hydrofreated and at least some ammonia is produced during hydrotreating, and further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.
4445. The method of claim 4433, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea.
4446. The method ofclaim 4433, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and, further comprising providing carbon dioxide from the formation to the urea synthesis process.
4447. The method ofclaim 4433, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and further comprising shifting at least a portion of carbon monoxide in the synthesis gas to carbon dioxide in a shift process, and further comprising providing at least a portion of the carbon dioxide from the shift process to the urea synthesis process.
4448. The method ofclaim 4433, wherein heating a selected section of the formation to a temperature to support reaction of hydrocarbon containing material in the formation to form synthesis gas comprises: heating zones adjacent to wellbores of one or more heat sources with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material withhi the zones with 02 in the 02 rich sfream; introducing the 02to the zones substantially by diffusion; allowing 02 in the 02 rich sfream to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and transfening heat from the zones to the selected section.
4449. The method ofclaim 4448, wherein temperatures sufficient to support reaction of hydrocarbon containing material within the zones with 02 range from approximately 200 °C to approximately 1200 °C.
4450. The method of claim 4448, wherein the one or more heat sources comprises one or more elecfrical heaters disposed in the foimation.
4451. The method ofclaim 4448, wherein the one or more heat sources comprises one or more natural distributed combustors.
4452. The method of claim 4448, wherein the one or more heat sources comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4453. The method of claim 4448, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heat sources.
4454. The method ofclaim 4433, wherein heating the selected section of the formation to a temperature to support reaction of hydrocarbon containing material in the formation to foπn synthesis gas comprises: infroducing the 02 rich sfream into the formation through a wellbore; fransporting 02 in the 02 rich sfream substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with 02 in the 02 rich sfream; and reacting the 02 within the portion of the selected section to generate heat and raise the temperature of the portion.
4455. The method of claim 4454, wherein the temperature sufficient to support an oxidation reaction with 02 ranges from approximately 200 °C to approximately 1200 °C.
4456. The method ofclaim 4454, wherein the one or more heat sources comprises one or more elecfrical heaters disposed in the formation.
4457. The method ofclaim 4454, wherein the one or more heat sources comprises one or more natural distributed combustors.
4458. The method of clahn 4454, wherein the one or more heat sources comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4459. The method of claim 4454, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heat sources.
4460. The method ofclaim 4433, further comprising confrolling the heating of at least the portion of the selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.
4461. The method of claim 4433 , wherein the synthesis gas generating fluid comprises liquid water.
4462. The method of claim 4433, wherein the synthesis gas generating fluid comprises steam.
4463. The method ofclaim 4433, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.
4464. The method of claim 4463, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.
4465. The method ofclaim 4433, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.
4466. The method ofclaim 4465, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.
4467. The method ofclaim 4433, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.
4468. A method for producing ammonia using a relatively low permeability formation containing heavy hydrocarbons, comprising: providing a first sfream comprising N2 and carbon dioxide to the formation; allowing at least a portion of the carbon dioxide in the ffrst sfream to adsorb in the foimation; producing a second stream from the formation, wherein the second sfream comprises a lower percentage of carbon dioxide than the first stream; providing at least a portion of the N2 in the second stream to an ammonia synthesis process.
4469. The method of claim 4468, wherein the second stteam comprises H2 from the formation.
4470. The method of claim 4468, wherein the first stteam is produced from a relatively low permeability formation containing heavy hydrocarbons.
4471. The method of claim 4470, wherein the first sfream is generated by reacting a oxidizing fluid with hydrocarbon containing material in the formation.
4472. The method ofclaim 4468, wherein the second sfream comprises H2 from the formation and, further comprising providing such H2 to the ammonia synthesis process.
4473. The method of claim 4468, further comprising using the ammonia synthesis process to generate ammonia.
4474. The method ofclaim 4473, wherein fluids produced during pyrolysis of a relatively low permeability foimation containing heavy hydrocarbons comprise ammonia and, further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.
4475. The method of claim 4473 , wherein fluids produced during pyrolysis of a hydrocarbon formation are hydrofreated and at least some ammonia is produced during hydrofreating, and further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.
4476. The method of claim 4473, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea.
4477. The method of claim 4473, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and, further comprising providing carbon dioxide from the formation to the urea synthesis process.
4478. The method of claim 4473, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and further comprising shifting at least a portion of carbon monoxide in the synthesis gas to carbon dioxide in a shift process, and further comprising providing at least a portion of the carbon dioxide from the shift process to the urea synthesis process.
4479. A method for freating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to the formation; allowing the heat to fransfer from one or more of the heat sources to a selected section of the formation such that heat from the heat sources pyrolyzes at least some hydrocarbons within the selected section, and wherein heat from the heat sources increases the permeability of at least a portion of the selected section; and producing a mixture comprising hydrocarbons from the formation.
4480. The method of clahn 4479, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the foimation, and wherein supeφosition of heat from at least the two heat sources increases the permeability of at least the portion of the selected section.
4481. The method of claim 4479, further comprising allowing heat to fransfer from at least one of the heat sources to the selected section to create thermal fractures in the formation wherein the thermal fractures substantially increase the permeability of the selected section.
4482. The method of claim 4479, wherein the heat is provided such that an average temperature in the selected section ranges from approximately about 270 °C to about 375 °C.
4483. The method ofclaim 4479, wherehi at least one of the heat sources comprises an electrical heater located in the foimation.
4484. The method of clahn 4479, wherein at least one of the heat sources is located in a heater well, and wherein at least one of the heater wells comprises a conduit located in the foπnation, and further comprising heathig the conduit by flowing a hot fluid through the conduit.
4485. The method ofclaim 4479, wherein at least some of the heat sources are ananged in a ttiangular pattern.
4486. The method of claim 4479, further comprising: monitoring a composition of the produced mixture; and controlling a pressure in at least a portion of the foimation to control the composition of the produced mixture.
4487. The method of claim 4486, wherein the pressure is confrolled by a valve proximate to a location where the mixture is produced.
4488. The method ofclaim 4486, wherein the pressure is confrolled such that pressure proximate to one or more of the heat sources is greater than a pressure proximate to a location where the fluid is produced.
4489. The method ofclaim 4479, wherein an average distance between heat sources is between about 2 m and about 8 m.
4490. A method for treating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to the formation; allowing the heat to ttansfer from one or more of the heat sources to a selected section of the formation such that heat from the heat sources pyrolyzes at least some hydrocarbons within the selected section, and wherehi heat from the heat sources vaporizes at least a portion of the hydrocarbons in the selected section; and producing a mixture comprising hydrocarbons from the foπnation.
4491. The method of claim 4490, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation, and wherein supeφosition of heat from at least the two heat sources vaporizes at least the portion of the hydrocarbons in the selected section.
4492. The method ofclaim 4490, further comprising allowing heat to fransfer from at least one of the heat sources to the selected section to create thermal fractures in the formation, wherein the thermal fractures substantially increase the peπneability of the selected section.
4493. The method of claim 4490, wherein the heat is provided such that an average temperature in the selected section ranges from approximately about 270 °C to about 375 °C.
4494. The method of claim 4490, wherein at least one of the heat sources comprises an
electrical heater located in the formation.
4495. The method ofclaim 4490, wherein at least one of the heat sources is located in a heater well, and wherein at least one of the heater wells comprises a conduit located in the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4496. The method of claim 4490, wherein at least some of the heat sources are ananged in a triangular pattern.
4497. The method ofclaim 4490, further comprising: monitoring a composition of the produced mixture; and controlling a pressure in at least a portion of the formation to confrol the composition of the produced mixture.
4498. The method of claim 4497, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.
4499. The method of claim 4497, wherein the pressure is controlled such that pressure proxhnate to one or more of the heat sources is greater than a pressure proximate to a location where the mixture is produced.
4500. The method of claim 4490, wherein an average distance between heat sources is between about 2 m and about 8 m.
4501. A method for treating a relatively low peπneability formation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to the formation, wherein at least one of the heat sources is located in a heater well; allowing the heat to transfer from one or more of the heat sources to a selected section of the formation such that heat from the heat sources pyrolyzes at least some hydrocarbons within the selected section, and wherein heat from the heat sources pressurizes at least a portion of the selected section; and producing a mixture comprising hydrocarbons from the foimation, wherein the mixture is produced from one or more heater wells.
4502. The method ofclaim 4501, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
4503. The method of claim 4501 , further comprising producing fluid from at least one heater well in which is positioned the heat source of the one or more heat sources.
4504. The method of claim 4501 , further comprising allowing heat to transfer from at least one of the heat sources to the selected section to create thermal fractures in the formation, wherein the thermal fractures substantially increase the permeability of the selected section.
4505. The method of claim 4501 , wherein the heat is provided such that an average temperature in the selected section ranges from approximately about 270 °C to about 375 °C.
4506. The method ofclaim 4501, wherein at least one of the heat sources comprises an electtical heater located in the formation.
4507. The method ofclaim 4501, wherein at least one of the heat sources is located in a heater well, and wherein at least one of the heater wells comprises a conduit located in the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4508. The method ofclaim 4501, wherein at least some of the heat sources are ananged in a triangular pattern.
4509. The method of clahn 4501, further comprising: monitoring a composition of the produced mixture; and confrolling a pressure in at least a portion of the formation to confrol the composition of the produced mixture.
4510. The method ofclaim 4509, wherein the pressure is confrolled by a valve proximate to a location where the mixture is produced.
4511. The method of claim 4509, wherein the pressure is confrolled such that pressure proximate to one or more of the heat sources is greater than a pressure proximate to a location where the mixture is produced.
4512. The method of claim 4501 wherein an average distance between heat sources is between about 2 m and about 8 m.
4513. A method for treating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to the formation; allowing the heat to ttansfer from one or more of the heat sources to a selected ffrst section of the formation such that heat from the heat sources creates a pyrolysis zone wherein at least some hydrocarbons are pyrolyzed within the first selected section, and allowing the heat to fransfer from one or more of the heat sources to a selected second section of the formation such that heat from the heat sources heats at least some hydrocarbons within the selected second section to a temperature less than the average temperature within the pyrolysis zone; and producing a mixture comprising hydrocarbons from the formation.
4514. The method of claim 4513, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from the at least two heat sources pyrolyzes at least some hydrocarbons within the selected first section of the foimation, and wherein supeφosition of heat from the at least two heat sources heats at least some hydrocarbons within the selected second section to a temperature less than the average temperature within the pyrolysis zone.
4515. The method ofclaim 4513, wherein at least some heated hydrocarbons within the selected second section flow into the pyrolysis zone.
4516. The method ofclaim 4513, wherein the heat decreases the viscosity of at least some of the hydrocarbons in the selected second section.
4517. The method of claim 4513, further comprising allowing heat to ttansfer from at least one of the heat sources to the selected first section to create thermal fractures in the foimation, wherein the thermal fractures substantially increase the permeability of the selected first section.
4518. The method ofclaim 4513, further comprising allowing heat to transfer from at least one of the heat sources to the selected second section to create thermal fractures in the formation, wherein the thermal fractures substantially increase the permeability of the selected second section.
4519. The method of claim 4513, wherein the heat is provided such that an average temperature in the selected first section ranges from approximately about 270 °C to about 375 °C.
4520. The method of claim 4513, wherein the heat is provided such that an average temperature in the selected second section ranges from approxhnately about 180 °C to about 250 °C.
4521. The method ofclaim 4513, wherein a viscosity of at least some of the hydrocarbons in the selected second section ranges from approxhnately about 20 centipoise to about 1000 centipoise.
4522. The method ofclaim 4513, wherein at least one of the heat sources comprises an electrical heater located in the formation.
4523. The method of claim 4513, wherein at least one of the heat sources is located in a heater well, and wherein at least one of the heater wells comprises a conduit located in the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4524. The method of claim 4513 , further comprising: monitoring a composition of the produced mixture; and controlling a pressure in at least a portion of the foimation to confrol the composition of the produced mixture.
4525. The method ofclaim 4524, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.
4526. The method of claim 4524, wherein the pressure is confrolled such that pressure proximate to one or more of the heat sources is greater than a pressure proximate to a location where the fluid is produced.
4527. The method of clahn 4513, wherein the pressure in the selected second section is substantially greater than the pressure in the selected first section.
4528. The method of claim 4513, wherein at least some of the heat sources are ananged in a triangular pattern.
4529. The method of claim 4513, wherein an average distance between heat sources in the selected first section is less than an average distance between heat sources in the selected second section.
4530. The method ofclaim 4513, wherein the heat is provided to the selected ffrst section before heat is provided to the selected second section.
4531. The method of clahn 4513, wherein the selected first section comprises at least one production well.
4532. The method ofclaim 4513, wherehi an average distance between heat sources in the selected first section is between about 2 m and about 10 m.
4533. The method ofclaim 4513, wherein an average distance between heat sources in the selected second section is between about 5 m and about 20 m.
4534. The method of claim 4513, wherein the selected first section comprises a planar region.
4535. The method ofclaim 4513, wherein at least one row of the heat sources provides heat to the planar region.
4536. The method ofclaim 4535 wherein a length of a row is between about 75 m and about 125 m.
4537. The method of claim 4534, wherein the planar region comprises a vertical hydraulic fracture.
4538. The method ofclaim 4537, wherein a width of the vertical hydraulic fracture is between about 0.3 cm and about 2.5 cm.
4539. The method ofclaim 4537, wherein a length of the vertical hydraulic fracture is between about 75 m and about 125 m.
4540. The method ofclaim 4513, wherein at least one ring comprising the heat sources provides heat to the selected ffrst section.
4541. The method of claim 4540, wherein at least one ring comprishig the heat sources provides heat to the selected second section.
4542. The method of claim 4540, wherein the ring comprises a polygon.
4543. The method ofclaim 4540, wherein the ring comprises a regular polygon.
4544. The method ofclaim 4540, wherein the ring comprises a hexagon.
4545. The method of clahn 4540, wherein the ring comprises a triangle.
4546. A method for freating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat from three or more heat sources to the formation; allowing the heat to fransfer from three or more of the heat sources to a selected section of the foπnation such that heat from the heat sources pyrolyzes at least some hydrocarbons within the selected section, and at least three of the heat sources are ananged in a substantially triangular pattern; and producing a mixture comprising hydrocarbons from the formation.
4547. The method ofclaim 4546, wherein supeφosition of heat from at least the three heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
4548. The method of claim 4546, wherein the mixture is produced from a production well located in a friangular region created by at least three heat sources.
4549. The method ofclaim 4546, further comprising allowing heat to fransfer from at least one of the heat sources to the selected section to create thermal fractures in the formation, wherein the thermal fractures substantially increase the permeability of the selected section.
4550. The method ofclaim 4546, wherein the heat is provided such that an average temperature in the selected section ranges from approximately about 270 °C to about 375 °C.
4551. The method ofclaim 4546, wherein at least one of the heat sources comprises an elecfrical heater located in the formation.
4552. The method ofclaim 4546, wherein at least one of the heat sources is located in a heater well, and wherein at least one of the heater wells comprises a conduit located in the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.
4553. The method ofclaim 4546, wherein at least some of the heat sources are ananged in a friangular pattern.
4554. The method ofclaim 4546, further comprising: monitoring a composition of the produced mixture; and controlling a pressure in at least a portion of the foπnation to control the composition of the produced mixture.
4555. The method of claim 4554, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.
4556. The method of clahn 4554, wherein the pressure is controlled such that pressure proximate to one or more of the heat sources is greater than a pressure proximate to a location where the fluid is produced.
4557. The method ofclaim 4546, wherein an average distance between heat sources is between about 2 m and about 8 m.
4558. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: a conduit configurable to be placed within an opening in the formation; a conductor configurable to be placed within the conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use; at least one centralizer configurable to be coupled to the conductor, wherein at least one cenfralizer inhibits movement of the conductor within the conduit during use; and wherein the system is configurable to allow heat to fransfer from the conductor to a section of the formation during use.
4559. The system ofclaim 4558, wherein at least one cenfralizer comprises elecfrically insulating material.
4560. The system ofclaim 4558, wherein at least one centralizer is configurable to inhibit arcing between the conductor and the conduit.
4561. The system ofclaim 4558, wherein at least one centralizer comprises ceramic material.
4562. The system ofclaim 4558, wherein at least one cenfralizer comprises at least one recess, wherein at least one recess is placed at ajunction of at least one cenfralizer and the first conductor, wherein at least one protrusion is formed on the first conductor at the junction to maintain a location of at least one cenfralizer on the first conductor, and wherein at least one protrusion resides substantially within at least one recess.
4563. The system of clahn 4562, wherein at least one protrusion comprises a weld.
4564. The system ofclaim 4562, wherein an elecfrically insulating material substantially covers at least one recess.
4565. The system ofclaim 4562, wherein a thermal plasma applied coating substantially covers at least one recess.
4566. The system ofclaim 4562, wherein a thermal plasma applied coating comprises alumina.
4567. The system ofclaim 4558, wherein the system is further configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the foimation during use.
4568. The system ofclaim 4558, further comprising an insulation layer configurable to be coupled to at least a portion of the conductor or at least one centralizer.
4569. The system ofclaim 4558, wherein at least one cenfralizer comprises a neck portion.
4570. The system ofclaim 4558, wherein at least one cenfralizer comprises one or more grooves.
4571. The system of claim 4558, wherein at least one centralizer comprises at least two portions, and wherein the portions are configurable to be coupled to the conductor to form at least one centralizer placed on the conductor.
4572. The system of claim 4558, wherein a thickness of the conductor is greater adjacent to a lean zone in the formation than a thickness of the conductor adjacent to a rich zone in the foimation such that more heat is provided to the rich zone.
4573. The system of claim 4558, wherein the system is configured to heat a relatively low permeability fonnation containing heavy hydrocarbons, and wherein the system comprises: a conduit configured to be placed within an opening in the formation; a conductor configured to be placed within the conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use; at least one centtalizer configured to be coupled to the conductor, wherein at least one centralizer inhibits movement of the conductor within the conduit during use; and wherein the system is configured to allow heat to fransfer from the conductor to a section of the formation during use.
4574. The system of claim 4558, wherein the system heats a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a conduit placed within an opening in the formation; a conductor placed within the conduit, wherein the conductor provides heat to at least a portion of the foimation; at least one centtalizer coupled to the conductor, wherein at least one centralizer inhibits movement of the conductor within the conduit; and wherein the system allows heat to transfer from the conductor to a section of the formation.
4575. The system ofclaim 4558, wherein the system is configurable to be removed from the opening in the formation.
4576. The system ofclaim 4558, further comprising a moveable thermocouple.
4577. The system ofclaim 4558, further comprising an isolation block.
4578. A system configurable to heat a relatively low peπneability formation containing heavy hydrocarbons, comprising: a conduit configurable to be placed withhi an opening in the formation;
a conductor configurable to be placed within the conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use; at least one centralizer configurable to be coupled to the conductor, wherein at least one cenfralizer inhibits movement of the conductor within the conduit during use wherein the system is configurable to allow heat to ttansfer from the conductor to a section of the formation during use; and wherein the system is configurable to be removed from the opening in the formation.
4579. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: applying an elecfrical cunent to a conductor to provide heat to at least a portion of the formation, wherein the conductor is placed within a conduit, wherein at least one centralizer is coupled to the conductor to inhibit movement of the conductor within the conduit, and wherein the conduit is placed within an opening in the formation; and allowing the heat to fransfer from the first conductor to a section of the formation.
4580. The method ofclaim 4579, further comprising pyrolyzing at least some hydrocarbons in the section of the formation.
4581. The method of claim 4579, further comprising inhibiting arcing between the conductor and the conduit.
4582. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: a conduit configurable to be placed within an opening in the foimation; a conductor configurable to be placed within a conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use; an insulation layer coupled to at least a portion of the conductor, wherein the insulation layer elecfrically insulates at least a portion of the conductor from the conduit during use; and wherein the system is configurable to allow heat to fransfer from the conductor to a section of the formation during use
4583. The system of claim 4582, wherein the insulation layer comprises a spiral insulation layer.
4584. The system of claim 4582, wherein the insulation layer comprises at least one metal oxide.
4585. The system ofclaim 4582, wherein the insulation layer comprises at least one alumina oxide.
4586. The system ofclaim 4582, wherein the insulation layer is configurable to be fastened to the conductor with a high temperature glue.
4587. The system ofclaim 4582, wherein the system is further configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the formation during use.
4588. The system ofclaim 4582, wherein the system is configured to heat a relatively low peπneability formation containing heavy hydrocarbons, and wherein the system comprises: a conduit configured to be placed within an opening in the foπnation; a conductor configured to be placed within a conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use; an insulation layer coupled to at least a portion of the conductor, wherein the insulation layer electrically insulates at least a portion of the conductor from the conduit during use; and wherein the system is configured to allow heat to transfer from the conductor to a section of the foimation during use.
4589. The system ofclaim 4582, wherein the system heats a relatively low permeability foπnation containing heavy hydrocarbons, and wherein the system comprises: a conduit placed within an opening in the formation; a conductor placed within a conduit, wherein the conductor provides heat to at least a portion of the foπnation; an insulation layer coupled to at least a portion of the conductor, wherein the insulation layer electtically insulates at least a portion of the conductor from the conduit; and wherein the system allows heat to fransfer from the conductor to a section of the formation.
4590. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: applying an electrical cunent to a conductor to provide heat to at least a portion of the fonnation, wherein the conductor is placed within a conduit, wherein an insulation layer is coupled to at least a portion of the conductor to electrically insulate at least a portion of the conductor from the conduit, and wherein the conduit is placed within an opening in the foπnation; and allowing the heat to transfer from the first conductor to a section of the formation.
4591. The method of claim 4590, further comprising pyrolyzing at least some hydrocarbons in the section of the formation.
4592. The method ofclaim 4590, further comprising inhibiting arcing between the conductor and the conduit.
4593. A method for making a conductor-in-conduit heat source for a relatively low permeability formation containing heavy hydrocarbons, comprising: placing at least one protrusion on a conductor; placing at least one cenfralizer on the conductor; and
placing the conductor within a conduit to form a conductor-in-conduit heat source, wherein at least one cenfralizer maintains a location of the conductor within the conduit.
4594. The method of claim 4593, wherein at least one cenfralizer comprises at least two portions, and wherein the portions are coupled to the conductor to form at least one centtalizer placed on the conductor.
4595. The method of clahn 4593, further comprising placing the conductor-in-conduit heat source in an opening in a relatively low permeability formation containing heavy hydrocarbons.
4596. The method ofclaim 4593, further comprising coupling an insulation layer on the conductor, wherein the insulation layer is configured to electrically insulate at least a portion of the conductor from the conduit.
4597. The method of clahn 4593, further comprising providing heat from the conductor-in-conduit heat source to at least a portion of the formation.
4598. The method ofclaim 4593, further comprising pyrolyzing at least some hydrocarbons in a selected section of the formation.
4599. The method of claim 4593, further comprising producing a mixture from a selected section of the formation.
4600. The method of claim 4593, wherein the conductor-in-conduit heat source is configurable to provide heat to the relatively low permeability formation containing heavy hydrocarbons.
4601. The method of claim 4593, wherein at least one cenfralizer comprises at least one recess placed at a junction of at least one centralizer on the conductor, and wherein at least one protrasion resides substantially within at least one recess.
4602. The method ofclaim 4601, further comprising at least partially covering at least one recess with an electrically insulating material.
4603. The method of claim 4601 , further comprising spraying an elecfrically insulating material to at least partially cover at least one recess.
4604. The method of claim 4593 , wherein placing at least one protrusion on the conductor comprises welding at least one protrusion on the conductor.
4605. The method ofclaim 4593, further comprising coiling the conductor-in-conduit heat source on a spool after forming the heat source.
4606. The method of claim 4593, further comprising uncoiling the heat source from the spool while placing the heat source in an opening in the formation.
4607. The method ofclaim 4593, wherein placing the conductor within a conduit comprises placing the conductor within a conduit that has been placed in an opening in the formation.
4608. The method of claim 4593, further comprising couplhig the conductor-in-conduit heat source to at least one additional conductor-in-conduit heat source.
4609. The method ofclaim 4593, wherein the conductor-in-conduit heat source is configurable to be installed into an opening in a relatively low permeability formation containing heavy hydrocarbons.
4610. The method of claim 4593, wherein the conductor-in-conduit heat source is configurable to be removed from an opening in a relatively low permeability formation containing heavy hydrocarbons.
4611. The method of claim 4593 , wherein the conductor-in-conduit heat source is configurable to heat to a section of the relatively low permeability formation containing heavy hydrocarbons, and wherein the heat pyrolyzes at least some hydrocarbons in the section of the formation during use.
4612. The method ofclaim 4593, wherein a thickness of the conductor configurable to be placed adjacent to a lean zone in the formation is greater than a thickness of the conductor configurable to be placed adjacent to a rich zone in the formation such that more heat is provided to the rich zone during use.
4613. A method for forming an opening in a relatively low permeability foπnation containing heavy hydrocarbons, comprising: forming a first opening in the formation; providing a series of magnetic fields from a plurality of magnets positioned along a portion of the first opening; and forming a second opening in the formation using magnetic tracking such that the second opening is positioned a selected distance from the first opening.
4614. The method of claim 4613, further comprising providing a magnetic sfring to a portion of the ffrst opening.
4615. The method ofclaim 4613, wherein the plurality of magnets is positioned within a casing.
4616. The method ofclaim 4613, wherein the plurality of magnets is positioned within a heater casing.
4617. The method ofclaim 4613, wherein the plurality of magnets is positioned within a perforated casing.
4618. The method ofclaim 4613, further comprising providing a magnetic string to a portion of the ffrst opening, wherein the magnetic string comprises two or more magnetic segments, and wherein the two or more segments are positioned such that the polarity of adjacent segments is reversed.
4619. The method of claim 4613, further comprising moving the magnetic fields within the first opening.
4620. The method ofclaim 4613, further comprishig moving the magnetic fields within the first opening such that the magnetic fields vary with time.
4621. The method ofclaim 4613, further comprising adjusting a position of the magnetic fields within the ffrst opening to increase a length of the second opening.
4622. The method ofclaim 4613, further comprising forming a plurality of openings adjacent to the ffrst opening.
4623. The method of claim 4613 , wherein the first opening comprises a non-metallic casing.
4624. The method ofclaim 4613, wherein the series of the magnetic fields comprises a first magnetic field and a second magnetic field and wherein a sfrength of the first magnetic differs from a sfrength of the second magnetic field.
4625. The method of clahn 4613, wherein the series of the magnetic fields comprises a first magnetic field and a second magnetic field and wherein a strength of the ffrst magnetic is about a sfrength of the second magnetic field.
4626. The method ofclaim 4613, wherein the ffrst opening comprises a center opening in a pattern of openings, and further comprishig forming a plurality of openings adjacent to the first opening.
4627. The method of claim 4613 , wherein the ffrst opening comprises a center opening in a pattern of openings, and further comprising forming a plurality of openings adjacent to the first opening, wherein each of the plurality of openings is positioned at the selected distance from the first opening.
4628. The method ofclaim 4613, further comprising providing at least one heat source within the first opening and at least one heat source within the second opening such that the heat sources can provide heat to at least a portion of the formation.
4629. A method for forming an opening in a relatively low permeability foπnation containing heavy hydrocarbons, comprising: forming a ffrst opening in the formation;
providing a magnetic sfring to the first opening, wherein the magnetic sfring comprises two or more magnetic segments, and wherein the magnetic segments are positioned such that the polarities of the segments are reversed; and forming a second opening in the formation using magnetic tracking such that the second opening is positioned a selected distance from the ffrst opening.
4630. The method of claim 4629, further comprising providing at least one heat source within the first opening and at least one heat source within the second opening such that the heat sources can provide heat to at least a portion of the formation.
4631. The method of claim 4629, wherein the two or more segments comprise a plurality of magnets.
4632. The method of claim 4629, further comprising providing a series of magnetic fields along a portion of the ffrst opening.
4633. The method ofclaim 4629, wherein a length of a segment conesponds to a distance between the first opening and the second opening.
4634. The method of claim 4629, further comprising moving the magnetic fields within the first opening.
4635. The method of claim 4629, further comprising moving the magnetic fields within the first opening such that the magnetic fields vary with time.
4636. The method ofclaim 4629, further comprising adjusting a position of the magnetic fields within the first opening to increase a length of the second opening.
4637. The method of claim 4629, further comprising forming a plurality of openings adjacent to the ffrst openhig.
4638. The method ofclaim 4629, wherein the first opening comprises a non-metallic casing.
4639. The method of claim 4629, wherein the series of the magnetic fields comprises a first magnetic field and a second magnetic field and wherehi a strength of the ffrst magnetic field differs from a sfrength of the second magnetic field.
4640. The method of claim 4629, wherein the series of the magnetic fields comprises a first magnetic field and a second magnetic field and wherein a sfrength of the first magnetic field is about a sfrength of the second magnetic field.
4641. The method of claim 4629, wherein the first opening comprises a center opening in a pattern of openings, and further comprising forming a plurality of openings adjacent to the first opening.
4642. The method ofclaim 4629, wherein the first opening comprises a center opening in a pattern of openings, and further comprising forming a plurality of openings adjacent to the first opening, wherein each of the plurality of openings is positioned at the selected distance from the first opening.
4643. The method ofclaim 4629, further comprising providing at least one heat source within the ffrst opening and at least one heat source within the second opening such that the heat sources can provide heat to at least a portion of the formation.
4644. The method of claim 4629, wherein the magnetic string is positioned within a casing.
4645. The method of claim 4629, wherein the magnetic sfring is positioned within a heater casing.
4646. A system for drilling openings in a relatively low permeability foimation containing heavy hydrocarbons, comprising: a drilling apparatus; a magnetic sfring, comprising: a conduit; and two or more magnetic segments positionable in the conduit, wherein the magnetic segments comprise a plurality of magnets ; and a sensor configurable to detect a magnetic field within the formation.
4647. The system ofclaim 4646, wherein the magnetic string further comprises one or more members configurable to inhibit movement of the magnetic segments relative to the conduit.
4648. The system of claim 4646, wherein the one or more magnetic segments are positioned such that a polarity of adjacent segments is reversed.
4649. The system ofclaim 4646, wherehi the magnetic string is positionable within a first opening in the formation.
4650. The system ofclaim 4646, wherein the magnetic string is positionable within a ffrst opening in the formation and wherein the magnetic string induces a magnetic field in a portion of the first opening.
4651. The system of clahn 4646, further comprising at least one heat source within a ffrst opening.
4652. The system ofclaim 4646, further comprising at least one heat source within a first opening and at least one heat source within a second opening such that the heat sources can provide heat to at least a portion of the formation.
4653. The system ofclaim 4646, further comprising providing a series of magnetic fields along a portion of a first opening.
4654. The system ofclaim 4646, wherein a length of a segment conesponds to a distance between the first opening and the second opening.
4655. The system ofclaim 4646, wherein the magnetic sfring is movable in a first opening.
4656. The system ofclaim 4646, wherein a position of the magnetic sfring in the first openhig can be adjusted to increase a length of a second opening.
4657. The system of clahn 4646, further comprising a first opening positioned in the formation and wherein the magnetic string is positionable in the ffrst opening.
4658. The system ofclaim 4646, further comprising a non-metallic casing.
4659. The system of claim 4646, wherein the magnetic segments comprises a first magnetic segment and a second magnetic segment and wherehi a length of the first magnetic segment differs from a length of the second magnetic segment.
4660. The system of clahn 4646, wherein the magnetic segments comprises a first magnetic segment and a second magnetic segment and wherein a length of the first magnetic segment is about the same as a length of the second magnetic segment.
4661. The system ofclaim 4646, further comprising a casing and wherein the magnetic string is positioned within the casing.
4662. A method of installing a conductor-in-conduit heat source of a desfred length in a relatively low permeability foπnation containing heavy hydrocarbons, comprising: assembling a conductor-in-conduit heat source of a desired length, comprising: placing a conductor within a conduit to form a conductor-in-conduit heat source; and coupling the conductor-in-conduit heat source to at least one additional conductor-in-conduit heat source to foπn a conductor-in-conduit heat source of the desired length, wherein the conductor is electrically coupled to the conductor of at least one additional conductor-in-conduit heat source and the conduit is electtically coupled to the conduit of at least one additional conductor-in-conduit heat source;
coiling the conductor-in-conduit heat source of the desired length after forming the heat source; and placing the conductor-in-conduit heat source of the desired length in an opening in a relatively low permeability formation containing heavy hydrocarbons.
4663. The method of clahn 4662, wherein the conductor-in-conduit heat source is configurable to provide heat to the relatively low permeability formation containing heavy hydrocarbons.
4664. The method of clahn 4662, wherein the conductor-in-conduit heat source of the desired length is removable from the opening in the relatively low permeability formation containing heavy hydrocarbons.
4665. The method ofclaim 4662, further comprising uncoiling the conductor-in-conduit heat source of the desfred length while placing the heat source in the opening.
4666. The method ofclaim 4662, further comprising placing at least one centralizer on the conductor.
4667. The method ofclaim 4662, further comprising placing at least one centtalizer on the conductor, wherein at least one cenfralizer inhibits movement of the conductor within the conduit.
4668. The method of claim 4662, further comprising placing an insulation layer on at least a portion of the conductor.
4669. The method ofclaim 4662, further comprising coiling the conductor-in-conduit heat source.
4670. The method of claim 4662, further comprising testing the conductor-in-conduit heat source and coiling the heat source.
4671. The method of claim 4662, wherein coupling the conductor-in-conduit heat source to at least one additional conductor-in-conduit heat source comprises welding the conductor-in-conduit heat source to at least one additional conductor-in-conduit heat source.
4672. The method ofclaim 4662, wherehi coupling the conductor-in-conduit heat source to at least one additional conductor-in-conduit heat source comprises shielded active gas welding the conductor-in-conduit heat source to at least one additional conductor-in-conduit heat source.
4673. The method of claim 4662, wherehi coupling the conductor-in-conduit heat source to at least one additional conductor-in-conduit heat source comprises shielded active gas welding the conductor-in-conduit heat source to at least one additional conductor-in-conduit heat source, and wherein using shielded active gas welding inhibits changes in the grain structure of the conductor or conduit during coupling.
4674. The method ofclaim 4662, wherein the assembling of the conductor-in-conduit heat source of the desired length is performed at a location proximate the relatively low permeability formation containing heavy hydrocarbons.
4675. The method ofclaim 4662, wherein the assembling of the conductor-in-conduit heat source of the desired length takes place sufficiently proximate the relatively low permeability foimation containing heavy hydrocarbons such that the conductor-in-conduit heat source can be placed directly in an opening of the formation after the heat source is assembled.
4676. The method of claim 4662, further comprising coupling at least one substantially low resistance conductor to the conductor-in-conduit heat source of the desfred length, wherein at least one substantially low resistance conductor is configured to be placed in an overburden of the formation.
4677. The method of claim 4676, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.
4678. The method ofclaim 4676, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises coupling a threaded end of at least one additional substantially low resistance conductor to a threaded end of at least one substantially low resistance conductor.
4679. The method ofclaim 4676, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises welding at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.
4680. The method ofclaim 4676, wherein at least one substantially low resistance conductor is coupled to the conductor-in-conduit heat source of the desired length during assembling of the heat source of the desfred length.
4681. The method of claim 4676, wherein at least one substantially low resistance conductor is coupled to the conductor-in-conduit heat source of the desired length after assembling of the heat source of the desfred length.
4682. The method of clahn 4662, further comprising ttansporting the coiled conductor-in-conduit heat source of the desfred length on a cart or train from an assembly location to the opening in the relatively low permeability foimation containing heavy hydrocarbons.
4683. The method of claim 4682, wherein the cart or train can be further used to transport more than one conductor-in-conduit heat source of the desired length to more than one opening in the relatively low permeability formation containing heavy hydrocarbons.
4684. The method ofclaim 4662, wherein the desfred length comprises a length determined for using the conductor-in-conduit heat source in a selected openmg in the relatively low permeability foπnation containing heavy hydrocarbons.
4685. The method of claim 4662, further comprising freating the conductor to increase an emissivity of the conductor.
4686. The method of claim 4685, wherein treating the conductor comprises roughening the surface of the conductor.
4687. The method of claim 4685, wherein treating the conductor comprises heathig the conductor to a temperature above about 750 °C in an oxidizing fluid atmosphere.
4688. The method ofclaim 4662, further comprising treating the conduit to increase an emissivity of the conduit.
4689. The method of claim 4662, further comprising coating at least a portion of the conductor or at least a portion of the conduit during assembly of the conductor-in-conduit heat source.
4690. The method ofclaim 4662, further comprising placing an insulation layer on at least a portion of the conductor-in-conduit heat source prior to placing the heat source in the opening in the relatively low peπneability foπnation containing heavy hydrocarbons.
4691. The method ofclaim 4690, wherein the insulation layer comprises a spiral insulation layer.
4692. The method of claim 4690, wherein the insulation layer comprises at least one metal oxide.
4693. The method of claim 4690, further comprising fastening at least a portion of the insulation layer to at least a portion of the conductor-in-conduit heat source with a high temperature glue.
4694. The method of claim 4662, further comprising providing heat from the conductor-in-conduit heat source of the desired length to at least a portion of the foimation.
4695. The method of claim 4662, wherein a thickness of the conductor configurable to be placed adjacent to a lean zone in the formation is greater than a thickness of the conductor configurable to be placed adjacent to a rich zone in the formation such that more heat is provided to the rich zone during use
4696. The method of claim 4662, further comprising pyrolyzing at least some hydrocarbons in a selected section of the formation.
4697. The method of claim 4662, further comprising producing a mixture from a selected section of the formation.
4698. A method for making a conductor-in-conduit heat source configurable to be used to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: placing a conductor within a conduit to form a conductor-in-conduit heat source; and shielded active gas welding the conductor-in-conduit heat source to at least one additional conductor-in- conduit heat source to form a conductor-in-conduit heat source of a desfred length, wherein the conductor is elecfrically coupled to the conductor of at least one additional conductor-in-conduit heat source and the conduit is elecfrically coupled to the conduit of at least one additional conductor-in-conduit heat source; and wherein the conductor-in-conduit heat source is configurable to be placed in an opening in the relatively low permeability foπnation containing heavy hydrocarbons, and wherein the conductor-in-conduit heat source is further configurable to heat a section of the relatively low permeability formation containing heavy hydrocarbons during use.
4699. The method ofclaim 4698, further comprising providing heat from the conductor-in-conduit heat source of the desfred length to at least a portion of the foimation.
4700. The method of claim 4698, further comprising pyrolyzing at least some hydrocarbons in a selected section of the foimation.
4701. The method of clahn 4698, further comprising producing a mixture from a selected section of the formation.
4702. The method of claim 4698, wherein the conductor and the conduit comprise stainless steel.
4703. The method of claim 4698, wherein the conduit comprises stainless steel.
4704. The method ofclaim 4698, wherehi the heat source is configurable to be removed from the formation.
4705. The method ofclaim 4698, further comprising providing a reducing gas during welding.
4706. The method of claim 4698, wherein the reducing gas comprises molecular hydrogen.
4707. The method ofclaim 4698, further comprising providing a reducing gas during welding such that welding occurs in an environment comprising less than about 25 % reducing gas by volume.
4708. The method ofclaim 4698, further comprising providing a reducing gas during welding such that welding occurs in an environment comprising about 10 % reducing gas by volume.
4709. A system configurable to heat a relatively low peπneability foπnation containing heavy hydrocarbons, comprising: a conduit configurable to be placed within an opening in the formation; a conductor configurable to be placed within the conduit, wherein the conductor is further configurable to provide heat to at least a portion of the fonnation during use, and wherein the conductor comprises at least two conductor sections coupled by shielded active gas welding; and wherein the system is configurable to allow heat to ttansfer from the conductor to a section of the foimation during use.
4710. The system ofclaim 4709, wherein the conduit comprises at least two conduit sections coupled by shielded active gas welding.
4711. The system of claim 4709, wherein the system is further configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the foimation during use.
4712. The system ofclaim 4709, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a conduit configured to be placed within an opening in the formation; a conductor configured to be placed within the conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use, and wherein the conductor comprises at least two conductor sections coupled by shielded active gas welding; and wherein the system is configured to allow heat to transfer from the conductor to a section of the formation during use.
4713. The system ofclaim 4709, wherein the system heats a relatively low permeability foπnation containing heavy hydrocarbons, and wherein the system comprises: a conduit placed within an opening in the formation; a conductor placed within the conduit, wherein the conductor provides heat to at least a portion of the foπnation during use, and wherein the conductor comprises at least two conductor sections coupled by shielded active gas welding; and wherein the system allows heat to transfer from the conductor to a section of the formation during use.
4714. The system ofclaim 4709, wherein the conductor-in-conduit heat source is configurable to be removed from the formation.
4715. A method for installing a heat source of a desfred length in a relatively low permeability formation containing heavy hydrocarbons, comprising:
assembling a heat source of a desfred length, wherein the assembling of the heat source of the desfred length is performed at a location proximate the relatively low permeability formation containing heavy hydrocarbons; coiling the heat source of the desired length after forming the heat source; and placing the heat source of the desfred length in an opening in a relatively low permeability formation containing heavy hydrocarbons, wherein placing the heat source in the opening comprises uncoiling the heat source while placing the heat source in the opening.
4716. The method ofclaim 4715, wherein the heat source is configurable to heat a section of the relatively low permeability formation containing heavy hydrocarbons.
4717. The method of claim 4716, wherein the heat pyrolyzes at least some hydrocarbons in the section of the formation during use.
4718. The method ofclaim 4715, further comprising coupling at least one substantially low resistance conductor to the heat source of the desired length, wherein at least one substantially low resistance conductor is configured to be placed in an overburden of the formation.
4719. The method of claim 4718, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.
4720. The method ofclaim 4718, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises coupling a threaded end of at least one additional substantially low resistance conductor to a threaded end of at least one substantially low resistance conductor.
4721. The method of claim 4718, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises welding at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.
4722. The method ofclaim 4715, further comprising transporting the heat source of the deshed length on a cart or train from an assembly location to the opening in the relatively low permeability formation containing heavy hydrocarbons.
4723. The method of clahn 4722, wherein the cart or train can be further used to fransport more than one heat source to more than one opening in the relatively low permeability formation containing heavy hydrocarbons.
4724. The method of claim 4722, wherein the heat source is configurable to removable from the opening.
4725. A method for installing a heat source of a desfred length in a relatively low permeability formation containing heavy hydrocarbons, comprising: assembling a heat source of a deshed length, wherein the assembling of the heat source of the desfred length is performed at a location proximate the relatively low peπneability formation containing heavy hydrocarbons; coiling the heat source of the desired length after forming the heat source; placing the heat source of the desired length in an opening in a relatively low permeability formation containing heavy hydrocarbons, wherein placing the heat source in the opening comprises uncoiling the heat source while placing the heat source in the opening; and wherein the heat source is configurable to be removed from the opening.
4726. The method ofclaim 4725, wherein the heat source is configurable to heat a section of the relatively low peπneability foπnation containing heavy hydrocarbons.
4727. The method ofclaim 4726, wherein the heat pyrolyzes at least some hydrocarbons in the section of the formation during use.
4728. The method ofclaim 4725, further comprising coupling at least one substantially low resistance conductor to the heat source of the desired length, wherein at least one substantially low resistance conductor is configured to be placed in an overburden of the formation.
4729. The method of claim 4728, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.
4730. The method ofclaim 4728, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises coupling a threaded end of at least one additional substantially low resistance conductor to a threaded end of at least one substantially low resistance conductor.
4731. The method ofclaim 4728, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises welding at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.
4732. The method of clahn 4725, further comprising transporting the heat source of the deshed length on a cart or train from an assembly location to the opening in the relatively low permeability formation containing heavy hydrocarbons.
4733. The method ofclaim 4725, wherein removing the heat source comprises recoiling the heat source.
4734. The method of claim 4725, wherein the heat source can be removed from the opening and installed in an alternate opening in the formation.
4735. A system configurable to heat a relatively low permeability foπnation containing heavy hydrocarbons, comprising: a conduit configurable to be placed withhi an opening in the formation; a conductor configurable to be placed within a conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use; an electrically conductive material configurable to be coupled to at least a portion of the conductor, wherein the electrically conductive material is configurable to lower an elecfrical resistance of the conductor in the overburden during use; and wherein the system is configurable to allow heat to fransfer from the conductor to a section of the formation during use.
4736. The system ofclaim 4735, further comprising an elecfrically conductive material configurable to be coupled to at least a portion of an inside surface of the conduit.
4737. The system ofclaim 4735, further comprising a substantially low resistance conductor configurable to be electtically coupled to the conductor and the elecfrically conductive material during use, wherein the substantially low resistance conductor is further configurable to be placed within an overburden of the formation.
4738. The system ofclaim 4737, wherein the low resistance conductor comprises carbon steel.
4739. The system of clahn 4735, wherein the elecfrically conductive material comprises metal tubing configurable to be clad to the conductor.
4740. The system ofclaim 4735, wherein the electrically conductive material comprises an electtically conductive coating configurable to be applied to the conductor.
4741. The system of claim 4735, wherein the electrically conductive material comprises a thermal plasma applied coating.
4742. The system of claim 4735, wherein the elecfrically conductive material is configurable to be sprayed on the conductor.
4743. The system ofclaim 4735, wherein the elecfrically conductive material comprises aluminum.
4744. The system ofclaim 4735, wherein the elecfrically conductive material comprises copper.
4745. The system of claim 4735, wherein the elecfrically conductive material is configurable to reduce the elecfrical resistance of the conductor in the overburden by a factor of greater than about 3.
4746. The system ofclaim 4735, wherein the elecfrically conductive material is configurable to reduce the electtical resistance of the conductor in the overburden by a factor of greater than about 15.
4747. The system ofclaim 4735, wherein the system is further configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the formation during use.
4748. The system of claim 4735, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a conduit configured to be placed within an opening in the formation; a conductor configured to be placed within a conduit, wherein the conductor is further configured to provide heat to at least a portion of the foimation during use; an elecfrically conductive material configured to be coupled to the conductor, wherein the electrically conductive material is further configured to lower an electrical resistance of the conductor in the overburden during use; and wherein the system is configured to allow heat to transfer from the conductor to a section of the foπnation during use.
4749. The system of claim 4735, wherein the system heats a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a conduit placed withhi an opening in the foπnation; a conductor placed within a conduit, wherein the conductor is provides heat to at least a portion of the formation during use; an electrically conductive material coupled to the conductor, wherein the electrically conductive material lowers an electtical resistance of the conductor in the overburden during use; and wherein the system allows heat to ttansfer from the conductor to a section of the formation during use.
4750. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: applying an electrical cunent to a conductor to provide heat to at least a portion of the formation, wherein the conductor is placed in a conduit, and wherein the conduit is placed in an opening in the foπnation, and wherein the conductor is coupled to an elecfrically conductive material; and allowing the heat to fransfer from the conductor to a section of the formation.
4751. The method of claim 4750, wherein the elecfrically conductive material comprises copper.
4752. The method ofclaim 4750, further comprising coupling an elecfrically conductive material to an inside surface of the conduit.
4753. The method of claim 4750, wherein the elecfrically conductive material comprises metal tubing clad to the substantially low resistance conductor.
4754. The method of clahn 4750, wherein the elecfrically conductive material reduces an electrical resistance of the substantially low resistance conductor in the overburden.
4755. The method ofclaim 4750, further comprising pyrolyzing at least some hydrocarbons within the formation.
4756. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: a conduit configurable to be placed within an opening in the foπnation; a conductor configurable to be placed within a conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use, and wherein the conductor has been treated to increase an emissivity of at least a portion of a surface of the conductor; and wherein the system is configurable to allow heat to transfer from the conductor to a section of the formation during use.
4757. The system of claim 4756, wherein at least a portion of the surface of the conductor has been roughened to increase the emissivity of the conductor.
4758. The system ofclaim 4756, wherein the conductor has been heated to a temperature above about 750 °C in an oxidizing fluid atmosphere to increase the emissivity of at least a portion of the surface of the conductor.
4759. The system of claim 4756, wherein the conduit has been freated to increase an emissivity of at least a portion of the surface of the conduit.
4760. The system ofclaim 4756, further comprising an electrically insulative, thermally conductive coating coupled to the conductor.
4761. The system ofclaim 4760, wherein the electtically insulative, thermally conductive coating is configurable to electtically insulate the conductor from the conduit.
4762. The system ofclaim 4760, wherein the elecfrically insulative, thermally conductive coating inhibits emissivity of the conductor from decreasing.
4763. The system of claim 4760, wherein the elecfrically insulative, thennally conductive coating substantially increases an emissivity of the conductor.
4764. The system ofclaim 4760, wherein the elecfrically insulative, thennally conductive coating comprises silicon oxide.
4765. The system ofclaim 4760, wherein the elecfrically insulative, thermally conductive coating comprises aluminum oxide.
4766. The system of claim 4760, wherein the electrically insulative, thermally conductive coating comprises refractive cement.
4767. The system ofclaim 4760, wherein the electrically insulative, thermally conductive coating is sprayed on the conductor.
4768. The system ofclaim 4756, wherein the system is fiuther configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the formation during use.
4769. The system ofclaim 4756, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a conduit configured to be placed within an opening in the formation; a conductor configured to be placed within a conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use, and wherein the conductor has been freated to increase an emissivity of at least a portion of a surface of the conductor; and wherein the system is configured to allow heat to fransfer from the conductor to a section of the formation during use.
4770. The system of clahn 4756, wherein the system heats a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a conduit placed within an opening in the formation; a conductor placed within a conduit, wherein the conductor provides heat to at least a portion of the formation during use, and wherein the conductor has been treated to increase an emissivity of at least a portion of a surface of the conductor; and wherein the system allows heat to fransfer from the conductor to a section of the formation during use.
4771. A heat source configurable to heat a relatively low permeability foπnation containing heavy hydrocarbons, comprising: a conduit configurable to be placed within an opening in the formation; and
a conductor configurable to be placed within a conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use, and wherein the conductor has been freated to increase an emissivity of at least a portion of a surface of the conductor.
4772. The heat source of claim 4771 , wherein at least a portion of the surface of the conductor has been roughened to increase the emissivity the conductor.
4773. The heat source ofclaim 4771, wherein the conductor has been heated to a temperature above about 750 °C in an oxidizing fluid atmosphere to increase the emissivity of at least at least a portion of the surface of the conductor.
4774. The heat source ofclaim 4771, wherein the conduit has been freated to increase an emissivity of at least a portion of the surface of the conduit.
4775. The heat source of claim 4771 , further comprising an elecfrically insulative, thermally conductive coating placed on the conductor.
4776. The heat source ofclaim 4775, wherein the electtically insulative, thermally conductive coating is configurable to electrically insulate the conductor from the conduit.
4777. The heat source ofclaim 4775, wherein the electrically insulative, thermally conductive coating substantially maintains an emissivity of the conductor.
4778. The heat source ofclaim 4775, wherein the electrically insulative, thennally conductive coating substantially increases an emissivity of the conductor.
4779. The heat source ofclaim 4775, wherein the electtically insulative, thermally conductive coating comprises silicon oxide.
4780. The heat source of claim 4775, wherein the elecfrically insulative, thermally conductive coating comprises aluminum oxide.
4781. The heat source of claim 4775, wherein the elecfrically insulative, thermally conductive coating comprises refractive cement.
4782. The heat source ofclaim 4775, wherein the elecfrically insulative, thermally conductive coating is sprayed on the conductor.
4783. The heat source ofclaim 4771, wherein the conductor is further configurable to provide heat to at least a portion of the foimation during use such that at least some hydrocarbons pyrolyze in the heated section of the formation during use.
4784. The heat source ofclaim 4771, wherein the heat source is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a conduit configured to be placed within an opening in the formation; a conductor configured to be placed within a conduit, wherein the conductor is further configured to provide heat to at least a portion of the foimation during use, and wherein the conductor has been freated to increase an emissivity of at least a portion of a surface of the conductor.
4785. The heat source ofclaim 4771, wherein the heat source heats a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a conduit placed within an opening in the formation; a conductor placed within a conduit, wherein the conductor provides heat to at least a portion of the formation, and wherein the conductor has been treated to increase an emissivity of at least a portion of a surface of the conductor.
4786. A method for forming an increased emissivity conductor-in-conduit heat source, comprising: treating a surface of a conductor to increase an emissivity of at least the surface of the conductor; placing the conductor within a conduit to form a conductor-in-conduit heat source; and wherein the conductor-in-conduit heat source is configurable to heat a relatively low permeability formation containing heavy hydrocarbons.
4787. The method of claim 4786, wherein treating the surface of the conductor comprises roughening at least a portion of the surface of the conductor.
4788. The method ofclaim 4786, wherein freating the surface of the conductor comprises heating the conductor to a temperature above about 750 °C in an oxidizing fluid atmosphere.
4789. The method ofclaim 4786, further comprising treating a surface of the conduit to increase an emissivity of at least a portion of the surface of the conduit.
4790. The method ofclaim 4786, further comprising placing the conductor-in-conduit heat source of the desfred length in an opening in a relatively low permeability formation containing heavy hydrocarbons.
4791. The method ofclaim 4786, further comprising assembling a conductor-in-conduit heat source of a desfred length, the assembling comprising: coupling the conductor-in-conduit heat source to at least one additional conductor-in-conduit heat source to form a conductor-in-conduit heat source of a desfred length, wherein the conductor is electrically coupled to the
conductor of at least one additional conductor-in-conduit heat source and the conduit is electtically coupled to the conduit of at least one additional conductor-in-conduit heat source; coiling the conductor-in-conduit heat source of the desired length after forming the heat source; and placing the conductor-in-conduit heat source of the desired length in an opening in a relatively low permeability formation containing heavy hydrocarbons.
4792. The method of claim 4786, wherein the conductor-in-conduit heat source is configurable to heat to a section of the relatively low permeability foπnation containing heavy hydrocarbons, and wherein the heat pyrolyzes at least some hydrocarbons in the section of the formation during use.
4793. A system configurable to heat a relatively low permeability formation containing heavy hydrocarbons, comprising: a heat source configurable to be placed in an opening in the formation, wherein the heat source is further configurable to provide heat to at least a portion of the formation during use; an expansion mechanism configurable to be coupled to the heat source, wherein the expansion mechanism is configurable to allow for movement of the heat source during use; and wherein the system is configurable to allow heat to transfer to a section of the formation during use.
4794. The system of claim 4793, wherein the expansion mechanism is configurable to allow for expansion of the heat source during use.
4795. The system ofclaim 4793, wherein the expansion mechanism is configurable to allow for confraction of the heat source during use.
4796. The system of claim 4793, wherein the expansion mechanism is configurable to allow for expansion of at least one component of the heat source during use.
4797. The system ofclaim 4793, wherein the expansion mechanism is configurable to allow for expansion and contraction of the heat source within a wellbore during use.
4798. The system ofclaim 4793, wherein the expansion mechanism comprises spring loading.
4799. The system ofclaim 4793, wherein the expansion mechanism comprises an accordion mechanism.
4800. The system of claim 4793, wherein the expansion mechanism is configurable to be coupled to a bottom of the heat source.
4801. The system of claim 4793, wherein the heat source is configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the formation during use.
4802. The system of clahn 4793, wherein the system is configured to heat a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a heat source configured to be placed in an opening in the foπnation, wherein the heat source is further configured to provide heat to at least a portion of the formation during use; an expansion mechanism configured to be coupled to the heat source, wherein the expansion mechanism is configured to allow for movement of the heat source during use; and wherein the system is configured to allow heat to ttansfer to a section of the formation during use.
4803. The system ofclaim 4793, wherein the system heats a relatively low permeability formation containing heavy hydrocarbons, and wherein the system comprises: a heat source placed in an opening in the formation, wherein the heat source provides heat to at least a portion of the formation during use; an expansion mechanism coupled to the heat source, wherein the expansion mechanism allows for movement of the heat source during use; and wherein the system allows heat to fransfer to a section of the formation during use.
4804. The system of claim 4793, wherein the heat source is removable.
4805. A system configurable to provide heat to a relatively low permeability formation containing heavy hydrocarbons, comprising: a conduit positionable in at least a portion of an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, and wherein a second end of the opening contacts the earth surface at a second location; and an oxidizer configurable to provide heat to a selected section of the formation by transferring heat through the conduit.
4806. The system ofclaim 4805, wherein heat from the oxidizer pyrolyzes at least some hydrocarbons in the selected section.
4807. The system ofclaim 4805, wherein the conduit is positioned in the opening.
4808. The system of clahn 4805, wherein the oxidizer is positionable in the conduit.
4809. The system ofclaim 4805, wherein the oxidizer is positioned in the conduit, and wherein the oxidizer is configured to heat the selected section.
4810. The system ofclaim 4805, wherein the oxidizer comprises a ring burner.
481 1. The system ofclaim 4805, wherein the oxidizer comprises an inline burner.
4812. The system ofclaim 4805, wherein the oxidizer is configurable to provide heat in the conduit.
4813. The system of claim 4805, further comprising an annulus foπned between a wall of the conduit and a wall of the opening.
4814. The system o claim 4805, wherein the oxidizer comprises a first oxidizer and a second oxidizer, and further comprising an annulus formed between a wall of the conduit and a wall of the openhig, wherein the second oxidizer is positionable in the annulus.
4815. The system ofclaim 4814, wherein the first oxidizer is configurable to provide heat in the conduit, and wherehi the second oxidizer is configurable to provide heat outside of the conduit.
4816. The system of claim 4814, wherehi heat provided by the ffrst oxidizer fransfers in the first conduit in a direction opposite of heat provided by the second oxidizer.
4817. The system of claim 4814, wherehi heat provided by the first oxidizer fransfers in the first conduit in a same direction as heat provided by the second oxidizer.
4818. The system ofclaim 4805, wherein the oxidizer is configurable to oxidize fuel to generate heat, and further comprising a recycle conduit configurable to recycle at least some of the fuel in the conduit to a fuel source.
4819. The system of claim 4805, wherein the oxidizer comprises a first oxidizer positioned in the conduit and a second oxidizer positioned in an annulus formed between a wall of the conduit and a wall of the opening, wherein the oxidizers are configurable to oxidize fuel to generate heat, and further comprising: a first recycle conduit configurable to recycle at least some of the fuel in the conduit to the second oxidizer; and a second recycle conduit configurable to recycle at least some of the fuel in the annulus to the first oxidizer.
4820. The system of claim 4805, further comprising insulation positionable proximate the oxidizer.
4821. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat to a conduit positioned in an opening in the formation, wherein a ffrst end of the opening contacts an earth surface at a first location, and wherein a second end of the openhig contacts the earth surface at a second location; and allowing the heat in the conduit to fransfer through the opening and to a sunounding portion of the formation.
4822. The method of claim 4821, further comprishig: providing fuel to an oxidizer; oxidizing at least some of the fuel; and allowing oxidation products to migrate through the opening, wherein the oxidation products comprise heat.
4823. The method of claim 4822, wherein the fuel is provided to the oxidizer proximate the first location, and wherein the oxidation products migrate towards the second location.
4824. The method of claim 4821 , wherein the oxidizer comprises a ring burner.
4825. The method ofclaim 4821, wherein the oxidizer comprises an inline burner.
4826. The method ofclaim 4821, further comprising recycling at least some fuel in the conduit.
4827. A system configurable to provide heat to a relatively low permeability formation containing heavy hydrocarbons, comprising: a conduit positionable in an opening in the foimation, wherein a ffrst end of the opening contacts an earth surface at a ffrst location, wherein a second end of the opening contacts the earth surface at a second location; an annulus foπned between a wall of the conduit and a wall of the opening; and a oxidizer configurable to provide heat to a selected section of the formation by transferring heat through the annulus.
4828. The system of claim 4827, wherein heat from the oxidizer pyrolyzes at least some hydrocarbons in the selected section.
4829. The system ofclaim 4827, wherein the conduit is positioned in the opening.
4830. The system ofclaim 4827, wherein the oxidizer comprises a first oxidizer and a second oxidizer, wherein the second oxidizer is positioned in the conduit, and wherein the second oxidizer is configured to heat the selected section.
4831. The system of claim 4827, wherein the oxidizer comprises a ring burner.
4832. The system of claim 4827, wherein the oxidizer comprises an inline burner.
4833. The system of claim 4830, wherein heat provided by the ffrst oxidizer fransfers in the first conduit in a direction opposite of heat provided by the second oxidizer.
4834. The system ofclaim 4827, wherein the oxidizer is configurable to oxidize fuel to generate heat, and further comprising a recycle conduit configurable to recycle at least some of the fuel in the conduit to a fuel source.
4835. The system ofclaim 4827, further comprising insulation positionable proximate the oxidizer.
4836. The system ofclaim 4827, wherein the conduit is positioned in the opening.
4837. The system ofclaim 4827, wherein the oxidizer is positioned in the annulus, and wherein the oxidizer is configured to heat the selected section.
4838. The system of clahn 4827, wherein the oxidizer comprises a first oxidizer and a second oxidizer.
4839. The system ofclaim 4838, wherein heat provided by the ffrst oxidizer fransfers through the opening in a direction opposite of heat provided by the second oxidizer.
4840. The system ofclaim 4827, wherein the oxidizer is configurable to oxidize fuel to generate heat, and further comprising a recycle conduit configurable to recycle at least some of the fuel in the annulus to a fuel source.
4841. The system ofclaim 4827, further comprising insulation positionable proxhnate the oxidizer.
4842. The system ofclaim 4838, wherein the first oxidizer and the second oxidizer comprise oxidizers, and wherein a first mixture of oxidation products generated by the first oxidizer flows countercurrent to a second mixture of oxidation products generated by the second heater.
4843. The system ofclaim 4838, wherein the first heater and the second heater comprise oxidizers, wherein fuel is oxidized by the oxidizers to generate heat, and further comprising a first recycle conduit to recycle fuel in the first conduit proximate the second location to the second conduit.
4844. The system ofclaim 4838, wherein the first oxidizer and the second oxidizer comprise oxidizers, wherein fuel is oxidized by the oxidizers to generate heat, and further comprising a second recycle conduit to recycle fuel in the second conduit proximate the first location to the first conduit.
4845. The system of claim 4827, further comprising a casing, wherein the conduit is positionable in the casing.
4846. The system ofclaim 4827, wherein the oxidizer comprises a first oxidizer positioned in the annulus and a second oxidizer positioned in the conduit, wherein the oxidizers are configurable to oxidize fuel to generate heat, and further comprising: a first recycle conduit configurable to recycle at least some of the fuel in the annulus to the second oxidizer; and
a second recycle conduit configurable to recycle at least some of the fuel in the conduit to the first oxidizer.
4847. An in situ method for heating a relatively low permeability fonnation containing heavy hydrocarbons, comprising: providing heat to an annulus formed between a wall of an opening in the formation and a wall of a conduit in the opening, wherein a first end of the opening contacts an earth surface at a ffrst location, and wherein a second end of the opening contacts the earth surface at a second location; and allowing the heat in the annulus to fransfer through the openhig and to a sunounding portion of the foimation.
4848. The method ofclaim 4847, further comprising: providing fuel to an oxidizer; oxidizing at least some of the fuel; and allowing oxidation products to migrate through the opening, wherehi the oxidation products comprise heat.
4849. The method of claim 4848, wherein the fuel is provided the oxidizer proxhnate the first location, and wherein the oxidation products migrate towards the second location.
4850. The method ofclaim 4847, wherein the oxidizer comprises a ring burner.
4851. The method ofclaim 4847, wherein the oxidizer comprises an inline burner.
4852. The method ofclaim 4847, further comprising recycling at least some fuel in the conduit.
4853. A system configurable to provide heat to a relatively low permeability formation containing heavy hydrocarbons, comprising: a first conduit positionable in an opening in the formation, wherein a first end of the opening contacts an earth surface at a ffrst location, wherehi a second end of the opening contacts the earth surface at a second location; a second conduit positionable in the opening; a first oxidizer configurable to provide heat to a selected section of the foπnation by transferring heat through the first conduit; and a second oxidizer configurable to provide heat to the selected section of the foπnation by fransfening heat through the second conduit..
4854. The system ofclaim 4853, wherein the first oxidizer is positionable in the first conduit.
4855. The system ofclaim 4853, wherehi the second oxidizer is positionable in the second conduit.
4856. The system ofclaim 4853, further comprising a casing positionable in the opening.
4857. The system ofclaim 4853, wherein at least a portion of the second conduit is positionable in the first conduit, and further comprising an annulus formed between a wall of the first conduit and a wall of the second conduit.
4858. The system of clahn 4853, wherein a portion of the second conduit is positionable proximate a portion of the first conduit.
4859. The system of claim 4853, wherein the ffrst oxidizer or the second oxidizer provide heat to at least a portion of the formation.
4860. The system ofclaim 4853, wherein the ffrst oxidizer and the second oxidizer provide heat to at least a portion of the formation concunently.
4861. The system ofclaim 4853, wherein the first oxidizer is positioned in the first conduit, wherein the second oxidizer is positioned in the second conduit, wherein the first oxidizer and the second oxidizer comprise oxidizers, and wherein a first flow of oxidation products from the first oxidizer flows in a direction opposite of a second flow of oxidation products from the second oxidizer.
4862. The system ofclaim 4853, further comprising: a first recycle conduit configurable to recycle at least some of the fuel in the first conduit to the second oxidizer; and a second recycle conduit configurable to recycle at least some of the fuel in the second conduit to the first oxidizer.
4863. An in situ method for heating a relatively low permeability foπnation containing heavy hydrocarbons, comprising: providing heat to a first conduit positioned in an opening in the formation, wherein a first end of the opening contacts an earth surface at a ffrst location, and wherein a second end of the opening contacts the earth surface at a second location; providing heat to a second conduit positioned in the opening in the formation; allowing the heat in the first conduit to fransfer through the opening and to a sunounding portion of the formation; and allowing the heat in the second conduit to transfer through the opening and to a sunounding portion of the formation;
4864. The method of claim 4863, wherein providing heat to the first conduit comprises providing fuel to an oxidizer.
4865. The method of claim 4863, wherein providing heat to the second conduit comprises providing fuel to an oxidizer.
4866. The method of claim 4863, wherein the ffrst fuel is provided to the ffrst conduit proximate the first location, and wherein the second fuel is provided to the second conduit proximate the second location.
4867. The method ofclaim 4863, wherem the first oxidizer or the second oxidizer comprises a ring burner.
4868. The method ofclaim 4863, wherein the first oxidizer or the second oxidizer an inline burner.
4869. The method ofclaim 4863, further comprising:
transfening heat through the first conduit in a first direction; and transfening heat in the second conduit in a second direction.
4870. The method of claim 4863, further comprising recycling at least some fuel in the first conduit to the second conduit; and recycling at least some fuel in the second conduit to the first conduit.
4871. A system configurable to provide heat to a relatively low permeability formation containing heavy hydrocarbons, comprising: a first conduit positionable in an openmg in the formation, wherein a first end of the opening contacts an earth surface at a ffrst location, wherehi a second end of the opening contacts the earth surface at a second location; a second conduit positionable in the first conduit; and at least one surface unit configurable to provide heat to the first conduit.
4872. The system ofclaim 4871, wherein the surface unit comprises a furnace.
4873. The system of claim 4871, wherein the surface unit comprises a burner.
4874. The system ofclaim 4871, wherein at least one surface unit is configurable to provide heat to the second conduit.
4875. The system ofclaim 4874, wherein the first conduit and the second conduit provide heat to at least a portion of the foimation.
4876. The system of claim 4874, wherein the first conduit provides heat to at least a portion of the formation.
4877. The system ofclaim 4874, wherein the second conduit provides heat to at least a portion of the formation.
4878. The system ofclaim 4871, further comprising a casing positionable in the opening.
4879. The method of claim 4871, wherein the first conduit and the second conduit are concentric.
4880. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a fluid using at least one surface unit; providing the heated fluid to a ffrst conduit wherein a portion of the ffrst conduit is positioned in an opening in the formation, wherem a first end of the opening contacts an earth surface at a ffrst location, and wherein a second end of the opening contacts the earth surface at a second location; allowing the heated fluid to flow into a second conduit, wherein the first conduit is positioned within the second conduit; and allowing heat from the ffrst and second conduit to ttansfer to a portion of the foπnation.
4881. The method of claim 4880, further comprising providing additional heat to the heated fluid using at least one surface unit proximate the second location.
4882. The method of claim 4880, wherein the fluid comprises an oxidizing fluid.
4883. The method of claim 4880, wherein the fluid comprises air.
4884. The method of claim 4880, wherein the fluid comprises flue gas.
4885. The method ofclaim 4880, wherein the fluid comprises steam.
4886. The method ofclaim 4880, wherein the fluid comprises fuel.
4887. The method ofclaim 4880, further comprising compressing the fluid prior to heating.
4888. The method of clahn 4880, wherein the surface unit comprises a furnace.
4889. The method of claim 4880, wherein the surface unit comprises an indirect furnace.
4890. The method of claim 4880, wherein the surface unit comprises a burner.
4891. The method of claim 4880, wherein the first conduit and the second conduit are concentric.
4892. A system configurable to provide heat to a relatively low permeability formation containing heavy hydrocarbons, comprising:
a conduit positionable in at least a portion of an opening in the formation, wherein a first end of the opening contacts an earth surface at a ffrst location, and wherein a second end of the opening contacts the earth surface at a second location; and at least two oxidizers configurable to provide heat to a portion of the foπnation.
4893. The system ofclaim 4892, wherein heat from the oxidizers pyrolyzes at least some hydrocarbons in the selected section.
4894. The system of clahn 4892, wherein the conduit comprises a fuel conduit.
4895. The system ofclaim 4892, wherein at least one oxidizer is positionable proximate the conduit.
4896. The system of claim 4892, wherein at least one oxidizer comprises a ring burner.
4897. The system of claim 4892, wherein at least one oxidizer comprises an inline burner.
4898. The system ofclaim 4892, further comprising insulation positionable proximate at least one oxidizer.
4899. The system ofclaim 4892, further comprising a casing comprising insulation proximate at least one oxidizer.
4900. An in situ method for heating a relatively low permeability foπnation containing heavy hydrocarbons, comprising: providing fuel to a conduit positioned in an openhig in the foπnation, wherein a ffrst end of the opening contacts an earth surface at a first location, and wherein a second end of the openhig contacts the earth surface at a second location; providing an oxidizmg fluid to the opening; oxidizing fuel in at least one oxidizer positioned proximate the conduit; and allowing heat to transfer to a portion of the formation.
4901. The method of claim 4900, further comprising providing steam to the conduit.
4902. The method ofclaim 4900, further comprising inhibiting coking within the conduit.
4903. The method ofclaim 4900, wherein the oxidizing fluid comprises afr.
4904. The method of claim 4900, wherein the oxidizing fluid comprises oxygen.
4905. The method of claim 4900, further comprising allowing oxidation products to exit the opening proxhnate the second location.
4906. The method ofclaim 4900, wherein the fuel is provided to proximate the first location, and wherein the oxidation products migrate towards the second location.
4907. The method ofclaim 4900, wherein the oxidizer comprises a ring burner.
4908. The method ofclaim 4900, wherein the oxidizer comprises an inline burner.
4909. The method ofclaim 4900, further comprising recycling at least some fuel in the conduit.
4910. The system ofclaim 4900, wherein the opening comprises a casing and further comprising insulating a portion of the casing proximate at least one oxidizer.
4911. The system ofclaim 4900, further comprising at least two oxidizers, wherein the oxidizers are positioned about 30 m apart.
4912. A system configurable to provide heat to a relatively low permeability formation containing heavy hydrocarbons, comprising: a conduit positionable in at least a portion of an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, and wherein a second end of the opening contacts the earth surface at a second location; and an oxidizing fluid source configurable to provide an oxidizing fluid to a reaction zone of the formation.
4913. The system of claim 4912, wherein the conduit comprises a conductor and wherein the conductor is configured to generate heat during application of an electtical cunent to the conduit.
4914. The system of claim 4912, wherehi the conduit comprises a low resistance conductor and wherein at least some of the low resistance conductor is positionable in an overburden.
4915. The system of claim 4912, wherein the oxidizing fluid source is configurable to provide at least some oxidizing fluid to the conduit at the first location and at the second location.
4916. The system of claim 4912, wherein the opening is configurable to allow products of oxidation to be produced from the formation.
4917. The system ofclaim 4912, wherein the oxidizing fluid reacts with at least some hydrocarbons and wherein the oxidizing fluid source is configurable to provide at least some oxidizing fluid to the first location and to the second location.
4918. The system ofclaim 4912, wherein the heat source is configurable to heat a reaction zone of the selected section to a temperature sufficient to support reaction of hydrocarbons in the selected section with an oxidizing fluid.
4919. The system ofclaim 4918, wherein the heat source is configurable to provide an oxidizing fluid to the selected section of the formation to generate heat during use.
4920. The system ofclaim 4918, wherein the generated heat transfers to a pyrolysis zone of the foimation.
4921. The system of claim 4912, further comprising an oxidizing fluid source configurable to provide an oxidizing fluid to the heat source, and wherein the conduit is configurable to provide the oxidizing fluid to the selected section of the foimation during use.
4922. The system of claim 4912, wherein the conduit comprises a low resistance conductor and a conductor, and wherein the conductor is further configured to generate heat during application of an elecfrical cunent to the conduit.
4923. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing an elecfrical cunent to a conduit positioned in an openmg in the formation; allowing heat to fransfer from the conduit to a reaction zone of the formation; providing at least some oxidizing fluid to the conduit; allowing the oxidizhig fluid to fransfer from the conduit to the reaction zone in the formation; allowing the oxidizing fluid to oxidize at least some hydrocarbons in the reaction zone to generate heat; and allowing at least some of the generated heat to transfer to a pyrolysis zone in the formation.
4924. The method ofclaim 4923, wherein at least a portion of the conduit is configured to generate heat during application of the electrical cunent to the conduit.
4925. The method of claim 4923 , further comprising: providing at least some oxidizing fluid to the conduit proximate a first end of the conduit; providing at least some oxidizing fluid to the conduit proximate a second end of the conduit; and wherein the first end of the conduit is positioned at a first location on a surface of the formation and wherein the second end of the conduit is positioned at a second location on the surface.
4926. The method of claim 4923, further comprising allowing the oxidizing fluid to move out of the conduit through orifices positioned on the conduit.
4927. The method ofclaim 4923, further comprishig removing products of oxidation through the opening during use.
4928. The method of claim 4923, wherein a first end of the opening is positioned at a first location on a surface of the formation and wherein a second end of the opening is positioned at a second location on the surface.
4929. The method of claim 4923, further comprising heating the reaction zone to a temperature sufficient to support reaction of hydrocarbons with an oxidizing fluid.
4930. The method ofclaim 4923, further comprising controlling a flow rate of the oxidizing fluid into the formation.
4931. The method of claim 4923, further comprising controlling a temperature in the pyrolysis zone.
4932. The method of claim 4923, further comprising removing products from oxidation through an opening in the formation during use.
4933. A method of using a computer system for modeling an in situ process for freating a relatively low permeability fonnation containing heavy hydrocarbons, comprising: providing at least one property of the formation to the computer system; providing at least one operating condition of the process to the computer system, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to ttansfer from the one or more heat sources to a selected section of the formation; and assessing at least one process characteristic of the in situ process using a simulation method on the computer system, and using at least one property of the formation and at least one operating condition.
4934. The method ofclaim 4933, wherein at least one process characteristic is assessed as function of time.
4935. The method ofclaim 4933, wherein the simulation method is a body-fitted finite difference simulation method.
4936. The method of claim 4933, wherein the simulation method is a space-fitted finite difference simulation method.
4937. The method ofclaim 4933, wherein the simulation method is a reservoir simulation method.
4938. The method of clahn 4933, wherein the simulation method simulates heat fransfer by conduction.
4939. The method ofclaim 4933, wherein the shnulation method simulates heat fransfer by convection.
4940. The method ofclaim 4933, wherein the simulation method simulates heat fransfer by radiation.
4941. The method ofclaim 4933, wherein the simulation method simulates heat fransfer in a near wellbore region.
4942. The method ofclaim 4933, wherein the simulation method assesses a temperature disfribution in the foπnation.
4943. The method ofclaim 4933, wherein at least one property of the formation comprises one or more materials from the formation.
4944. The method ofclaim 4943, wherein one material comprises mineral matter.
4945. The method of claim 4943, wherein one material comprises organic matter.
4946. The method of claim 4933, wherehi at least one property of the foπnation comprises one or more phases.
4947. The method of claim 4946, wherein one phase comprises a water phase.
4948. The method ofclaim 4946, wherein one phase comprises an oil phase.
4949. The method of claim 4948, wherein the oil phase comprises one or more components.
4950. The method of claim 4946, wherein one phase comprises a gas phase.
4951. The method of claim 4950, wherein the gas phase comprises one or more components.
4952. The method of claim 4933, wherein at least one property of the foπnation comprises a porosity of the fonnation.
4953. The method ofclaim 4933, wherein at least one property of the formation comprises a peπneability of the formation.
4954. The method of clahn 4953, wherein the permeability depends on the composition of the foπnation.
4955. The method of clahn 4933, wherein at least one property of the formation comprises a saturation of the formation.
4956. The method ofclaim 4933, wherein at least one property of the fonnation comprises a density of the formation.
4957. The method ofclaim 4933, wherein at least one property of the foπnation comprises a thermal conductivity of the formation.
4958. The method ofclaim 4933, wherein at least one property of the foimation comprises a volumetric heat capacity of the formation.
4959. The method ofclaim 4933, wherein at least one property of the formation comprises a compressibility of the formation.
4960. The method ofclaim 4933, wherein at least one property of the formation comprises a composition of the foπnation.
4961. The method ofclaim 4933, wherein at least one property of the formation comprises a thickness of the foimation.
4962. The method of clahn 4933, wherein at least one property of the formation comprises a depth of the formation.
4963. The method ofclaim 4933, wherein at least one property comprises one or more chemical components.
4964. The method of claim 4963, wherein one component comprises a pseudo-component.
4965. The method of clahn 4933, wherein at least property comprises one or more kinetic parameters.
4966. The method of claim 4933, wherein at least one property comprises one or more chemical reactions.
4967. The method of claim 4966, wherein a rate of at least one chemical reaction depends on a pressure of the fonnation.
4968. The method of claim 4966, wherein a rate of at least one chemical reaction depends on a temperature of the formation.
4969. The method ofclaim 4966, wherein at least one chemical reaction comprises a pre-pyrolysis water generation reaction.
4970. The method of claim 4966, wherein at least one chemical reaction comprises a hydrocarbon generating reaction.
4971. The method of claim 4966, wherein at least one chemical reaction comprises a coking reaction.
4972. The method ofclaim 4966, wherein at least one chemical reaction comprise a cracking reaction.
4973. The method of claim 4966, wherein at least one chemical reaction comprises a synthesis gas reaction.
4974. The method of claim 4933, wherein at least one process characteristic comprises an API gravity of produced fluids.
4975. The method of claim 4933, wherein at least one process characteristic comprises an olefin content of produced fluids.
4976. The method ofclaim 4933, wherein at least one process characteristic comprises a carbon number distribution of produced fluids.
4977. The method ofclaim 4933, wherein at least one process characteristic comprises an ethene to ethane ratio of produced fluids.
4978. The method ofclaim 4933, wherein at least one process characteristic comprises an atomic carbon to hydrogen ratio of produced fluids.
4979. The method ofclaim 4933, wherein at least one process characteristic comprises a ratio of non- condensable hydrocarbons to condensable hydrocarbons of produced fluids.
4980. The method of claim 4933, wherein at least one process characteristic comprises a pressure in the formation
4981. The method ofclaim 4933, wherein at least one process characteristic comprises total mass recovery from the formation.
4982. The method ofclaim 4933, wherein at least one process characteristic comprises a production rate of fluid produced from the formation.
4983. The method of claim 4933, wherein at least one operating condition comprises a pressure.
4984. The method of clahn 4933, wherein at least one operating condition comprises a temperature.
4985. The method of claim 4933 , wherein at least one operating condition comprises a heating rate.
4986. The method ofclaim 4933, wherein at least one operating condition comprises a process time.
4987. The method ofclaim 4933, wherein at least one operating condition comprises a location of producer wells.
4988. The method of clahn 4933, wherein at least one operating condition comprises an orientation of producer wells.
4989. The method ofclaim 4933, wherein at least one operating condition comprises a ratio of producer wells to heater wells.
4990. The method of claim 4933, wherein at least one operating condition comprises a spacing between heater wells.
4991. The method ofclaim 4933, wherein at least one operating condition comprises a distance between an overburden and horizontal heater wells.
4992. The method ofclaim 4933, wherein at least one operating condition comprises a pattern of heater wells.
4993. The method ofclaim 4933, wherein at least one operating condition comprises an orientation of heater wells.
4994. A method of using a computer system for modeling an in situ process for treating a relatively low permeability formation containing heavy hydrocarbons, comprising: simulating a heat input rate to the formation from two or more heat sources on the computer system, wherein heat is allowed to fransfer from the heat sources to a selected section of the formation; providing at least one desired parameter of the in situ process to the computer system; and controlling the heat input rate from the heat sources to achieve at least one desired parameter.
4995. The method ofclaim 4994, wherein the heat is allowed to fransfer from the heat sources substantially by conduction.
4996. The method of claim 4994, wherein the heat input rate is simulated with a body-fitted finite difference simulation method.
4997. The method of claim 4994, wherein simulating the heat input rate from two or more heat sources comprises simulating a model of one or more heat sources with symmetry boundary conditions.
4998. The method ofclaim 4994, wherein supeφosition of heat from the two or more heat sources pyrolyzes at least some hydrocarbons within the selected section of the formation.
4999. The method of claim 4994, wherein at least one desfred parameter comprises a selected process characteristic.
5000. The method of claim 4994, wherein at least one desfred parameter comprises a selected temperature.
5001. The method ofclaim 4994, wherein at least one desired parameter comprises a selected heating rate.
5002. The method of claim 4994, wherein at least one desired parameter comprises a desired product mixture produced from the formation.
5003. The method of claim 4994, wherein at least one desfred parameter comprises a desfred product mixture produced from the foπnation, and wherein the desfred product mixture comprises a selected composition.
5004. The method ofclaim 4994, wherein at least one desfred parameter comprises a selected pressure.
5005. The method of claim 4994, wherein at least one desired parameter comprises a selected heating time.
5006. The method of claim 4994, wherein at least one desired parameter comprises a market parameter.
5007. The method ofclaim 4994, wherein at least one desfred parameter comprises a price of crude oil.
5008. The method of claim 4994, wherein at least one desired parameter comprises an energy cost.
5009. The method of claim 4994, wherein at least one desired parameter comprises a selected molecular hydrogen to carbon monoxide volume ratio.
5010. A method of using a computer system for modeling an in situ process for treating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing at least one heat input property to the computer system; assessing heat injection rate data for the formation using a first simulation method on the computer system;
providing at least one property of the foπnation to the computer system; assessing at least one process characteristic of the in situ process from the heat injection rate data and at least one property of the formation using a second shnulation method; and wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation
501 1. The method ofclaim 5010, wherein at least one process characteristic is assessed as a function of time.
5012. The method ofclaim 5010, wherein assessing heat injection rate data comprises simulating heating of the formation.
5013. The method of claim 5010, wherein the heating is confrolled to obtain a desfred parameter.
5014. The method of clahn 5010, wherein determining at least one process characteristic comprises simulating heating of the foπnation.
5015. The method ofclaim 5014, wherein the heating is confrolled to obtain a desired parameter.
5016. The method of claim 5010, wherein the first simulation method is a body-fitted finite difference simulation method.
5017. The method ofclaim 5010, wherein the second simulation method is a space-fitted finite difference simulation method.
5018. The method ofclaim 5010, wherein the second simulation method is a reservoir simulation method.
5019. The method ofclaim 5010, wherein the first simulation method simulates heat transfer by conduction.
5020. The method of clahn 5010, wherehi the first simulation method simulates heat transfer by convection.
5021. The method ofclaim 5010, wherein the first simulation method simulates heat transfer by radiation.
5022. The method ofclaim 5010, wherein the second simulation method shnulates heat ttansfer by conduction.
5023. The method ofclaim 5010, wherein the second simulation method simulates heat ttansfer by convection.
5024. The method of claim 5010, wherein the first simulation method simulates heat fransfer in a near wellbore region.
5025. The method ofclaim 5010, wherein the first shnulation method determines a temperature disttibution in the fonnation.
5026. The method ofclaim 5010, wherein at least one heat input property comprises a property of the fonnation.
5027. The method ofclaim 5010, wherein at least one heat input property comprises a heat fransfer property. '
5028. The method ofclaim 5010, wherein at least one heat input property comprises an initial property of the formation.
5029. The method ofclaim 5010, wherein at least one heat input property comprises a heat capacity.
5030. The method ofclaim 5010, wherein at least one heat input property comprises a thermal conductivity.
5031. The method ofclaim 5010, wherein the heat injection rate data comprises a temperature disfribution within the formation.
5032. The method ofclaim 5010, wherein the heat injection rate data comprises a heat input rate.
5033. The method of clahn 5032, wherein the heat input rate is confrolled to maintain a specified maximum temperature at a point in the foπnation.
5034. The method ofclaim 5010, wherein the heat injection rate data comprises heat flux data.
5035. The method ofclaim 5010, wherein at least one property of the foπnation comprises one or more materials in the formation.
5036. The method ofclaim 5035, wherein one material comprises mineral matter.
5037. The method of claim 5035, wherein one material comprises organic matter.
5038. The method ofclaim 5010, wherein at least one property of the formation comprises one or more phases.
5039. The method of claim 5038, wherein one phase comprises a water phase.
5040. The method of claim 5038, wherein one phase comprises an oil phase.
5041. The method of claim 5040, wherein the oil phase comprises one or more components.
5042. The method ofclaim 5038, wherein one phase comprises a gas phase.
5043. The method of claim 5042, wherein the gas phase comprises one or more components.
5044. The method ofclaim 5010, wherein at least one property of the foπnation comprises a porosity of the formation.
5045. The method ofclaim 5010, wherein at least one property of the formation comprises apermeability of the formation.
5046. The method ofclaim 5045, wherein the permeability depends on the composition of the formation.
5047. The method ofclaim 5010, wherein at least one property of the formation comprises a saturation of the formation.
5048. The method ofclaim 5010, wherein at least one property of the formation comprises a density of the formation.
5049. The method ofclaim 5010, wherein at least one property of the formation comprises a theπnal conductivity of the foπnation.
5050. The method ofclaim 5010, wherein at least one property of the foπnation comprises a volumetric heat capacity of the formation.
5051. The method ofclaim 5010, wherein at least one property of the formation comprises a compressibility of the formation.
5052. The method of claim 5010, wherein at least one property of the foπnation comprises a composition of the foπnation.
5053. The method of clahn 5010, wherein at least one property of the formation comprises a thickness of the formation.
5054. The method of claim 5010, wherein at least one property of the formation comprises a depth of the foπnation.
5055. The method of claim 5010, wherein at least one property of the formation comprises one or more chemical components.
5056. The method of clahn 5055, wherein at least one chemical component comprises a pseudo-component.
5057. The method ofclaim 5010, wherein at least one property of the fonnation comprises one or more kinetic parameters.
5058. The method ofclaim 5010, wherein at least one property of the fonnation comprises one or more chemical reactions.
5059. The method ofclaim 5058, wherein a rate of at least one chemical reaction depends on a pressure of the formation.
5060. The method ofclaim 5058, wherehi a rate of at least one chemical reaction depends on a temperature of the formation.
5061. The method ofclaim 5058, wherein at least one chemical reaction comprises a pre-pyrolysis water generation reaction.
5062. The method ofclaim 5058, wherein at least one chemical reaction comprises a hydrocarbon generating reaction.
5063. The method of clahn 5058, wherein at least one chemical reaction comprises a coking reaction.
5064. The method ofclaim 5058, wherehi at least one chemical reaction comprises a cracking reaction.
5065. The method of claim 5058, wherein at least one chemical reaction comprises a synthesis gas reaction.
5066. The method ofclaim 5010, wherein at least one process characteristic comprises an API gravity of produced fluids.
5067. The method ofclaim 5010, wherein at least one process characteristic comprises an olefin content of produced fluids.
5068. The method ofclaim 5010, wherein at least one process characteristic comprises a carbon number disttibution of produced fluids.
5069. The method ofclaim 5010, wherein at least one process characteristic comprises an ethene to ethane ratio of produced fluids.
5070. The method of clahn 5010, wherein at least one process characteristic comprises an atomic carbon to hydrogen ratio of produced fluids.
5071. The method of clahn 5010, wherein at least one process characteristic comprises a ratio of non- condensable hydrocarbons to condensable hydrocarbons of produced fluids.
5072. The method ofclaim 5010, wherein at least one process characteristic comprises a pressure in the formation.
5073. The method ofclaim 5010, wherem at least one process characteristic comprises a total mass recovery from the formation.
5074. The method ofclaim 5010, wherein at least one process characteristic comprises a production rate of fluid produced from the formation.
5075. The method ofclaim 5010, further comprising: assessing modified heat injection rate data using the first simulation method at a specified time of the second simulation method based on at least one heat input property of the formation at the specified time; assessing at least one process characteristic of the in situ process as a function of time from the modified heat injection rate data and at least one property of the formation at the specified time using the second shnulation method.
5076. A method of using a computer system for modeling an in situ process for freating a relatively low peπneability foπnation containing heavy hydrocarbons, comprising: providing one or more model parameters for the in situ process to the computer system; assessing one or more simulated process characteristics based on one or more model parameters using a simulation method; modifying one or more model parameters such that at least one simulated process characteristic matches or approximates at least one real process characteristic; assessing one or more modified simulated process characteristics based on the modified model parameters; and wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation.
5077. The method of claim 5076, further comprising using the simulation method with the modified model parameters to determine at least one operating condition of the in situ process to achieve a desfred parameter.
5078. The method ofclaim 5076, wherein the simulation method comprises a body-fitted finite difference shnulation method.
5079. The method ofclaim 5076, wherein the simulation method comprises a space-fitted finite difference simulation method.
5080. The method of claim 5076, wherehi the simulation method comprises a reservofr simulation method.
5081. The method of claim 5076, wherein the real process characteristics comprise process characteristics obtained from laboratory experhnents of the in situ process.
5082. The method of claim 5076, wherein the real process characteristics comprise process characteristics . obtained from field test experiments of the in situ process.
5083. The method ofclaim 5076, further comprising comparing the simulated process characteristics to the real process characteristics as a function of time.
5084. The method of claim 5076, further comprising associating differences between the simulated process characteristics and the real process characteristics with one or more model parameters.
5085. The method of claim 5076, wherein at least one model parameter comprises a chemical component.
5086. The method of claim 5076, wherein at least one model parameter comprises a kinetic parameter.
5087. The method of claim 5086, wherein the kinetic parameter comprises an order of a reaction.
5088. The method ofclaim 5086, wherein the kinetic parameter comprises an activation energy.
5089. The method ofclaim 5086, wherein the kinetic parameter comprises a reaction enthalpy.
5090. The method of claim 5086, wherehi the kinetic parameter comprises a frequency factor.
5091. The method ofclaim 5076, wherein at least one model parameter comprises a chemical reaction.
5092. The method of claim 5091 , wherein at least one chemical reaction comprises a pre-pyrolysis water generation reaction.
5093. The method ofclaim 5091, wherein at least one chemical reaction comprises a hydrocarbon generating reaction.
5094. The method of claim 5091, wherein at least one chemical reaction comprises a coking reaction.
5095. The method ofclaim 5091, wherein at least one chemical reaction comprises a cracking reaction.
5096. The method of clahn 5091, wherein at least one chemical reaction comprises a synthesis gas reaction.
5097. The method ofclaim 5076, wherein one or more model parameters comprise one or more properties.
5098. The method ofclaim 5076, wherein at least one model parameter comprises a relationship for the dependence of a property on a change in conditions in the formation.
5099. The method ofclaim 5076, wherein at least one .model parameter comprises an expression for the dependence of porosity on pressure in the formation.
5100. The method of claim 5076, wherein at least one model parameter comprises an expression for the dependence of permeability on porosity.
5101. The method of claim 5076, wherein at least one model parameter comprises an expression for the dependence of thermal conductivity on composition of the formation.
5102. A method of using a computer system for modeling an in situ process for freating a relatively low permeability fonnation containing heavy hydrocarbons, comprising: assessing at least one operating condition of the in situ process using a simulation method based on one or more model parameter; modifying at least one model parameter such that at least one simulated process characteristic of the in situ process matches or approximates at least one real process characteristic of the in situ process; assessing one or more modified simulated process characteristics based on the modified model parameters; and wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the fonnation, and wherein the in situ process comprises allowing the heat to ttansfer from the one or more heat sources to a selected section of the foπnation
5103. The method of claim 5102, wherein at least one operating condition is assessed to achieve at least one desfred parameter.
5104. The method of claim 5102, wherein the real process characteristic comprises a process characteristic from a field test of the in situ process.
5105. The method of claim 5102, wherein the simulation method comprises a body-fitted finite difference simulation method.
5106. The method of clahn 5102, wherein the simulation method comprises a space-fitted finite difference simulation method.
5107. The method of claim 5102, wherein the shnulation method comprises a reservoir simulation method.
5108. A method of modeling a process of treating a relatively low permeability fonnation containing heavy hydrocarbons in situ using a computer system, comprising: providing one or more model parameters to the computer system; assessing one or more ffrst process characteristics based on the one or more model parameters using a first simulation method on the computer system; assessing one or more second process characteristics based on one or more model parameters using a second shnulation method on the computer system; modifying one or more model parameters such that at least one first process characteristic matches or approximates at least one second process characteristic; and wherein the in situ process comprises providmg heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation.
5109. The method of claim 5108, further comprising assessing one or more third process characteristics based on the one or more modified model parameters using the second simulation method.
5110. The method of claim 5108, wherehi modifying one or more model parameters such that at least one first process characteristic matches or approximates at least one second process characteristic further comprises: assessing at least one set of first process characteristics based on at least one set of modified model parameters using the first simulation method; and assessing the set of modified model parameters that results in at least one first process characteristic that matches or approximates at least one second process characteristic.
51 11. The method of claim 5108, wherein the first simulation method comprises a body-fitted finite difference simulation method.
51 12. The method of claim 5108, wherein the second simulation method comprises a space-fitted finite difference simulation method.
5113. The method of claim 5108, wherehi at least one first process characteristic comprises a process characteristic at a shaφ interface in the foπnation.
5114. The method of claim 5108, wherein at least one first process characteristic comprises a process characteristic at a combustion front in the foimation.
5115. The method ofclaim 5108, wherein modifying the one or more model parameters comprises changing the order of a chemical reaction.
5116. The method of claim 5108, wherein modifying the one or more model parameters comprises adding one or more chemical reactions.
5117. The method ofclaim 5108, wherein modifying the one or more model parameters comprises changing an activation energy.
5118. The method of claim 5108, wherein modifying the one or more model parameters comprises changing a frequency factor.
5119. A method of using a computer system for modeling an in situ process for treating a relatively low peπneability formation containing heavy hydrocarbons, comprising: providing to the computer system one or more values of at least one operating condition of the in situ process, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation; assessing one or more values of at least one process characteristic conesponding to one or more values of at least one operating condition using a simulation method; providing a desfred value of at least one process characteristic for the in situ process to the computer system; and assessing a desfred value of at least one operating condition to achieve the desfred value of at least one process characteristic from the assessed values of at least one process characteristic and the provided values of at least one operating condition.
5120. The method of clahn 5119, further comprising operating the in situ system using the desired value of at least one operating condition.
5121. The method of claim 5119, wherein the process comprises providing heat from one or more heat sources to at least one portion of the fonnation.
5122. The method of claim 5119, wherein the process comprises allowing heat to ttansfer from one or more heat sources to a selected section of the foπnation.
5123. The method of claim 5119, wherein a value of at least one process characteristic comprises the process characteristic as a function of time.
5124. The method of claim 5119, further comprising determining a value of at least one process characteristic based on the desired value of at least one operating condition using the simulation method.
5125. The method of clahn 5119, wherein determining the desfred value of at least one operating condition comprises inteφolating the desired value from the determined values of at least one process characteristic and the provided values of at least one operating condition.
5126. A method of using a computer system for modeling an in situ process for freating a relatively low permeability foimation containing heavy hydrocarbons, comprising: providing a desired value of at least one process characteristic for the in situ process to the computer system, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the foπnation, and wherein the in situ process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and assessing a value of at least one operating condition to achieve the desfred value of at least one process characteristic, wherein such assessing comprises using a relationship between at least one process characteristic and at least one operating condition for the in situ process, wherein such relationship is stored on a database accessible by the computer system.
5127. The method ofclaim 5126, further comprising operating the in situ system using the desired value of at least one operating condition.
5128. The method of claim 5126, wherein the process comprises providing heat from one or more heat sources to at least one portion of the formation.
5129. The method of claim 5126, wherein the process comprises providing heat to ttansfer from one or more heat sources to a selected section of the formation.
5130. The method ofclaim 5126, wherein the relationship is determined from one or more simulations of the in situ process using a simulation method.
5131. The method of claim 5126, wherein the relationship comprises one or more values of at least one process characteristic and conesponding values of at least one operating condition.
5132. The method ofclaim 5126, wherein the relationship comprises an analytical function.
5133. The method of claim 5126, wherein determining the value of at least one operating condition comprises inteφolating the value of at least one operating condition from the relationship.
5134. The method ofclaim 5126, wherein at least one process characteristic comprises a selected composition of produced fluids.
5135. The method of clahn 5126, wherein at least one operating condition comprises a pressure.
5136. The method ofclaim 5126, wherein at least one operating condition comprises a heat input rate.
5137. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modelmg an in situ process for treating a relatively low penneability formation containing heavy hydrocarbons, the method comprising: providing at least one property of the foπnation to the computer system; providmg at least one operating condition of the process to the computer system, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the foimation, and wherein the in situ process comprises allowing the heat to ttansfer from the one or more heat sources to a selected section of the foimation; and assessing at least one process characteristic of the in situ process using a simulation method on the computer system, and using at least one property of the foπnation and at least one operating condition.
5138. A canier medium comprising program instructions, wherein the program instractions are computer- executable to implement a method comprishig: providing at least one property of the foπnation to the computer system; providing at least one operating condition of the process to the computer system, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation; and assessing at least one process characteristic of the in situ process using a simulation method on the computer system, and using at least one property of the fonnation and at least one operating condition.
5139. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for freating a relatively low permeability formation containing heavy hydrocarbons, the method comprising:
simulating a heat input rate to the formation from two or more heat sources on the computer system, wherein heat is allowed to fransfer from the heat sources to a selected section of the formation; providing at least one desired parameter of the in situ process to the computer system; and controlling the heat input rate from the heat sources to achieve at least one desfred parameter.
5140. A canier medium comprising program instructions, wherein the program instructions are computer- executable to implement a method comprising: simulating a heat input rate to the formation from two or more heat sources on the computer system, wherein heat is allowed to transfer from the heat sources to a selected section of the formation; providing at least one deshed parameter of the in situ process to the computer system; and controlling the heat input rate from the heat sources to achieve at least one desired parameter.
5141. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for freating a relatively low permeability formation containing heavy hydrocarbons, the method comprising: providing at least one heat input property to the computer system; assessing heat injection rate data for the formation using a first simulation method on the computer system; providing at least one property of the foimation to the computer system; assessing at least one process characteristic of the in situ process from the heat injection rate data and at least one property of the foimation using a second simulation method; and wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation
5142. A canier medium comprising program instructions, wherein the program instractions are computer- executable to implement a method comprising: providing at least one heat input property to the computer system; assessing heat injection rate data for the formation using a first simulation method on the computer system; providing at least one property of the foimation to the computer system; assessing at least one process characteristic of the in situ process from the heat injection rate data and at least one property of the foπnation using a second shnulation method; and wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the foπnation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the fonnation
5143. A system, comprising:
a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for freating a relatively low permeability formation containing heavy hydrocarbons, the method comprising: providing one or more model parameters for the in situ process to the computer system; assessing one or more simulated process characteristics based on one or more model parameters using a simulation method; modifying one or more model parameters such that at least one simulated process characteristic matches or approximates at least one real process characteristic; assessing one or more modified simulated process characteristics based on the modified model parameters; and wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the foπnation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the foπnation.
5144. A canier medium comprising program instractions, wherein the program instructions are computer- executable to implement a method comprising: providing one or more model parameters for the in situ process to the computer system; assessing one or more simulated process characteristics based on one or more model parameters using a simulation method; modifying one or more model parameters such that at least one simulated process characteristic matches or approximates at least one real process characteristic; assessing one or more modified simulated process characteristics based on the modified model parameters; and wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to ttansfer from the one or more heat sources to a selected section of the formation.
5145. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for freating a relatively low permeability foimation containing heavy hydrocarbons, the method comprishig: assessing at least one operating condition of the in situ process using a simulation method based on one or more model parameter;
modifying at least one model parameter such that at least one simulated process characteristic of the in situ process matches or approximates at least one real process characteristic of the in situ process; assessing one or more modified simulated process characteristics based on the modified model parameters; and wherehi the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation simulated process characteristics based on the modified model parameters.
5146. A canier medium comprising program instructions, wherein the program insfructions are computer- executable to implement a method comprising: assessing at least one operating condition of the in situ process using a simulation method based on one or more model parameter; modifying at least one model parameter such that at least one simulated process characteristic of the in situ process matches or. approximates at least one real process characteristic of the in situ process; assessing one or more modified simulated process characteristics based on the modified model parameters; and wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation
5147. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement , a method of using a computer system for modeling an in situ process for treating a relatively low permeability formation containing heavy hydrocarbons, the method comprising: providing one or more model parameters to the computer system; assessing one or more ffrst process characteristics based on one or more model parameters using a first simulation method on the computer system; assessing one or more second process characteristics based on one or more model parameters using a second simulation method on the computer system; modifying one or more model parameters such that at least one ffrst process characteristic matches or approximates at least one second process characteristic; and wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to ttansfer from the one or more heat sources to a selected section of the formation
5148. A canier medium comprising program instructions, wherein the program insfructions are computer- executable to implement a method comprising: providing one or more model parameters to the computer system; assessing one or more first process characteristics based on one or more model parameters using a first simulation method on the computer system; assessing one or more second process characteristics based on one or more model parameters using a second simulation method on the computer system; modifying one or more model parameters such that at least one first process characteristic matches at least one second process characteristic; and wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation.
5149. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherehi the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a relatively low permeability foπnation containing heavy hydrocarbons, the method comprising: providing to the computer system one or more values of at least one operating condition of the in situ process, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the foimation; assessing one or more values of at least one process characteristic conesponding to one or more values of at least one operating condition using a simulation method; providing a desfred value of at least one process characteristic for the in situ process to the computer system; and assessing a desfred value of at least one operating condition to achieve the desfred value of at least one process characteristic from the assessed values of at least one process characteristic and the provided values of at least one operating condition.
5150. A canier medium comprising program instructions, wherein the program insfructions are computer- executable to implement a method comprising: providing to the computer system one or more values of at least one operating condition of the in situ process, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the foπnation; assessing one or more values of at least one process characteristic conesponding to one or more values of at least one operating condition using a shnulation method;
providing a desired value of at least one process characteristic for the in situ process to the computer system; and assessing a desired value of at least one operating condition to achieve the desfred value of at least one process characteristic from the assessed values of at least one process characteristic and the provided values of at least one operating condition.
5151. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a relatively low permeability foimation containing heavy hydrocarbons, the method comprising: providing a desfred value of at least one process characteristic for the in situ process to the computer system, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to ttansfer from the one or more heat sources to a selected section of the formation; and assessing a value of at least one operating condition to achieve the desired value of at least one process characteristic, wherein such assessing comprises using a relationship between at least one process characteristic and at least one operating condition for the in situ process, wherein such relationship is stored on a database accessible by the computer system.
5152. A canier medium comprising program instractions, wherein the program instructions are computer- executable to hnplement a method comprising: providing a desired value of at least one process characteristic for the in situ process to the computer system, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and assessing a value of at least one operating condition to achieve the desired value of at least one process characteristic, wherein such assessing comprises using a relationship between at least one process characteristic and at least one operating condition for the in situ process, wherein such relationship is stored on a database accessible by the computer system.
5153. A method of ushig a computer system for operating an in situ process for freathig a relatively low permeability formation containing heavy hydrocarbons, comprising: operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; providing at least one operating parameter of the in situ process to the computer system; and
using at least one parameter with a simulation method and the computer system to provide assessed infoπnation about the in situ process.
5154. The method of clahn 5153, wherein one or more of the operating parameters comprise a thickness of a treated portion of the foπnation.
5155. The method of claim 5153, wherein one or more of the operating parameters comprise an area of a treated portion of the foπnation.
5156. The method of claim 5153, wherein one or more of the operating parameters comprise a volume of a freated portion of the foπnation.
5157. The method ofclaim 5153, wherein one or more of the operating parameters comprise a property of the formation.
5158. The method of claim 5153, wherein one or more of the operating parameters comprise a heat capacity of the formation.
5159. The method of claim 5153, wherein one or more of the operating parameters comprise a permeability of the formation.
5160. The method ofclaim 5153, wherein one or more of the operating parameters comprise a density of the formation.
5161. The method of clahn 5153, wherein one or more of the operating parameters comprise a thennal conductivity of the foπnation.
5162. The method ofclaim 5153, wherein one or more of the operating parameters comprise a porosity of the formation.
5163. The method ofclaim 5153, wherehi one or more of the operating parameters comprise a pressure.
5164. The method ofclaim 5153, wherein one or more of the operating parameters comprise a temperature.
5165. The method of claim 5153, wherein one or more of the operating parameters comprise a heating rate.
5166. The method of claim 5153, wherein one or more of the operating parameters comprise a process time.
5167. The ethod of claim 5153, wherein one or more of the operating parameters comprises a location of producer wells.
5168. The method of claim 5153, wherein one or more of the operating parameters comprise an orientation of producer wells.
5169. The method ofclaim 5153, wherein one or more of the operating parameters comprise a ratio of producer wells to heater wells.
5170. The method ofclaim 5153, wherein one or more of the operating parameters comprise a spacing between heater wells.
5171. The method ofclaim 5153, wherein one or more of the operating parameters comprise a distance between an overburden and horizontal heater wells.
5172. The method ofclaim 5153, wherein one or more of the operating parameters comprise atype of pattern of heater wells.
5173. The method ofclaim 5153, wherein one or more of the operating parameters comprise an orientation of heater wells.
5174. The method of claim 5153, wherein one or more of the operating parameters comprise a mechanical property.
5175. The method ofclaim 5153, wherein one or more of the operating parameters comprise subsidence of the formation.
5176. The method ofclaim 5153, wherein one or more of the operating parameters comprise fracture progression in the formation.
5177. The method ofclaim 5153, wherein one or more of the operating parameters comprise heave of the formation.
5178. The method of clahn 5153, wherein one or more of the operating parameters comprise compaction of the formation.
5179. The method of claim 5153, wherein one or more of the operating parameters comprise shear deformation of the formation.
5180. The method ofclaim 5153, wherein the assessed infoπnation comprises information relating to properties of the foπnation.
5181. The method ofclaim 5153, wherein the assessed information comprises a relationship between one or more operating parameters and at least one other operating parameter.
5182. The method of claim 5153, wherein the computer system is remote from the in situ process.
5183. The method ofclaim 5153, wherein the computer system is located at or near the in situ process.
5184. The method ofclaim 5153, wherein at least one parameter is provided to the computer system using hardwire communication.
5185. The method ofclaim 5153, wherein at least one parameter is provided to the computer system using internet communication.
5186. The method of claim 5153, wherein at least one parameter is provided to the computer system using wireless communication.
5187. The method ofclaim 5153, wherein the one or more parameters are monitored using sensors in the foπnation.
5188. The method of clahn 5153 , wherein at least one parameter is provided automatically to the computer system.
5189. The method ofclaim 5153, wherein using at least one parameter with a simulation method comprises performing a simulation and obtaining properties of the formation.
5190. A method of using a computer system for operating an in situ process for treating a relatively low permeability formation containing heavy hydrocarbons, comprising: operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation; providing at least one operating parameter of the in situ process to the computer system; using at least one parameter with a simulation method and the computer system to provide assessed information about the in situ process; and using the assessed infonnation to operate the in situ process.
5191. The method of claim 5190, further comprising providing the assessed infonnation to a computer system used for controlling the in situ process.
5192. The method of claim 5190, wherein the computer system is remote from the in situ process.
5193. The method of claim 5190, wherein the computer system is located at or near the in situ process.
5194. The method of claim 5190, wherein using the assessed information to operate the in situ process comprises: modifying at least one operating parameter; and operating the in situ process with at least one modified operating parameter.
5195. A method of using a computer system for operating an in situ process for treating a relatively low permeability formation containing heavy hydrocarbons, comprising operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to ttansfer from the one or more heat sources to a selected section of the formation; providing at least one operating parameter of the in situ process to the computer system; using at least one parameter with a first simulation method and the computer system to provide assessed information about the in situ process; and obtaining information from a second simulation method and the computer system using the assessed infonnation and a desfred parameter.
5196. The method of claim 5195, further comprising using the obtained information to operate the in situ process.
5197. The method of claim 5195, wherein the first simulation method is the same as the second simulation method.
5198. The method of claim 5195, further comprising providing the obtained infoπnation to a computer system used for controlling the in situ process.
5199. The method ofclaim 5195, wherein using the obtained information to operate the in situ process comprises: modifying at least one operating parameter; and operating the in situ process with at least one modified operating parameter.
5200. The method of claim 5195, wherein the obtained information comprises at least one operating parameter for use in the in situ process that achieves the desired parameter.
5201. The method of clahn 5195, wherein the computer system is remote from the in situ process.
5202. The method of claim 5195, wherein the computer system is located at or near the in situ process.
5203. The method of claim 5195, wherein the desired parameter comprises a selected gas to oil ratio.
5204. The method ofclaim 5195, wherein the desired parameter comprises a selected production rate of fluid produced from the formation.
5205. The method ofclaim 5195, wherein the desfred parameter comprises a selected production rate of fluid at a selected time produced from the foπnation.
5206. The method of claim 5195, wherein the desired parameter comprises a selected olefin content of produced fluids.
5207. The method ofclaim 5195, wherein the desfred parameter comprises a selected carbon number disfribution of produced fluids.
5208. The method of claim 5195, wherein the deshed parameter comprises a selected ethene to ethane ratio of produced fluids.
5209. The method of claim 5195, wherein the desfred parameter comprises a desfred atomic carbon to hydrogen ratio of produced fluids.
5210. The method ofclaim 5195, wherein the desfred parameter comprises a selected gas to oil ratio of produced fluids.
5211. The method ofclaim 5195, wherein the desfred parameter comprises a selected pressure in the formation.
5212. The method ofclaim 5195, wherein the desired parameter comprises a selected total mass recovery from the formation.
5213. The method of claim 5195, wherein the desfred parameter comprises a selected production rate of fluid produced from the foimation.
5214. A system, comprising: a CPU; a data memory coupled to the CPU; and
a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for operating an in situ process for treating a relatively low peπneability formation containing heavy hydrocarbons, comprising: operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to ttansfer from the one or more heat sources to a selected section of the foπnation; providing at least one operating parameter of the in situ process to the computer system; and using at least one parameter with a simulation method and the computer system to provide assessed information about the in situ process.
5215. A canier medium comprising program instructions, wherein the program instructions are computer- executable to implement a method comprising: operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the foimation; providing at least one operating parameter of the in situ process to the computer system; and using at least one parameter with a simulation method and the computer system to provide assessed information about the in situ process.
5216. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for operating an in situ process for treating a relatively low permeability formation containing heavy hydrocarbons, comprising: operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation; providing at least one operating parameter of the in situ process to the computer system; using at least one parameter with a simulation method and the computer system to provide assessed information about the in situ process; and using the assessed information to operate the in situ process.
5217. A canier medium comprising program instructions, wherein the program instructions are computer- executable to hnplement a method comprising:
operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the foimation, and wherein the in situ process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the foπnation; providing at least one operating parameter of the in situ process to the computer system; using at least one parameter with a shnulation method and the computer system to provide assessed information about the in situ process; and using the assessed information to operate the in situ process.
5218. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for operating an in situ process for freating a relatively low permeability formation containing heavy hydrocarbons, comprising: operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the fonnation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation; providing at least one operating parameter of the in situ process to the computer system; using at least one parameter with a first simulation method and the computer system to provide assessed information about the in situ process; and obtaining information from a second simulation method and the computer system using the assessed information and a desired parameter.
5219. A canier medium comprising program instructions, wherein the program instructions are computer- executable to implement a method comprising: operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation; providing at least one operating parameter of the in situ process to the computer system; using at least one parameter with a first simulation method and the computer system to provide assessed information about the in situ process; and obtaining infonnation from a second simulation method and the computer system using the assessed information and a desired parameter.
5220. A method of modeling one or more stages of a process for freating a relatively low permeability foimation containing heavy hydrocarbons in situ with a simulation method using a computer system, comprising:
providing at least one property of the formation to the computer system; providing at least one operating condition for the one or more stages of the in situ process to the computer system, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to ttansfer from the one or more heat sources to a selected section of the formation; assessing at least one process characteristic of the one or more stages using the shnulation method.
5221. The method ofclaim 5220, wherein the simulation method is a body-fitted finite difference simulation method.
5222. The method ofclaim 5220, wherein the simulation method is a reservoir simulation method.
5223. The method of claim 5220, wherein the simulation method is a space-fitted finite difference simulation method.
5224. The method of claim 5220, wherein the simulation method simulates heating of the fonnation.
5225. The method ofclaim 5220, wherein the simulation method simulates fluid flow in the foπnation.
5226. The method of claim 5220, wherein the simulation method simulates mass ttansfer in the foπnation.
5227. The method of claim 5220, wherein the simulation method simulates heat ttansfer in the formation.
5228. The method of clahn 5220, wherein the simulation method simulates chemical reactions in the one or more stages of the process in the foπnation.
5229. The method ofclaim 5220, wherein the simulation method simulates removal of contaminants from the formation.
5230. The method ofclaim 5220, wherehi the simulation method shnulates recovery of heat from the formation.
5231. The method of claim 5220, wherein the simulation method shnulates injection of fluids into the formation.
5232. The method ofclaim 5220, wherein the one or more stages comprise heating of the foimation.
5233. The method ofclaim 5220, wherein the one or more stages comprise generation of pyrolyzation fluids.
5234. The method ofclaim 5220, wherein the one or more stages comprise remediation of the formation.
5235. The method of clahn 5220, wherehi the one or more stages comprise shut-in of the formation.
5236. The method of claim 5220, wherein at least one operating condition of a remediation stage is the flow rate of ground water into the foπnation.
5237. The method of claim 5220, wherein at least one operating condition of a remediation stage is the flow rate of injected fluids into the fonnation.
5238. The method of claim 5220, wherein at least one process characteristic of a remediation stage is the concenfration of contaminants in the formation.
5239. The method of claim 5220, further comprising: providing to the computer system at least one set of operating conditions for at least one of the stages of the in situ process, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the foπnation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation; providing to the computer system at least one desired process characteristic for at least one of the stages of the in situ process; and assessing at least one additional operating condition for at least one of the stages that achieves at least one desired process characteristic for at least one of the stages.
5240. A method of using a computer system for modeling an in situ process for freating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing at least one property of the formation to a computer system; providing at least one operating condition to the computer system; assessing at least one process characteristic of the in situ process, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and assessing at least one deformation characteristic of the foπnation using a simulation method from at least one property, at least one operating condition, and at least one process characteristic.
5241. The method of claim 5240, wherein the in situ process comprises two or more heat sources.
5242. The method of claim 5240, wherein the in situ process provides heat from one or more heat sources to at least one portion of the fonnation.
5243. The method of claim 5240, wherein the simulation method comprises a finite element simulation method.
5244. The method of claim 5240, wherein the formation comprises a freated portion and an untreated portion.
5245. The method of clahn 5240, wherein at least one deformation characteristic comprises subsidence.
5246. The method of claim 5240, wherein at least one deformation characteristic comprises heave.
5247. The method ofclaim 5240, wherein at least one defonnation characteristic comprises compaction.
5248. The method ofclaim 5240, wherein at least one defonnation characteristic comprises shear deformation.
5249. The method of claim 5240, wherein at least one operating condition comprises a pressure.
5250. The method of claim 5240, wherein at least one operating condition comprises a temperature.
5251. The method of claim 5240, wherein at least one operating condition comprises a process time.
5252. The method of claim 5240, wherein at least one operating condition comprises a rate of pressure increase.
5253. The method ofclaim 5240, wherein at least one operating condition comprises a heating rate.
5254. The method of claim 5240, wherein at least one operatmg condition comprises a width of a freated portion of the formation.
5255. The method ofclaim 5240, wherein at least one operating condition comprises a thickness of a treated portion of the formation.
5256. The method ofclaim 5240, wherein at least one operating condition comprises a thickness of an overburden of the formation.
5257. The method ofclaim 5240, wherein at least one process characteristic comprises a pore pressure disfribution in the formation.
5258. The method ofclaim 5240, wherein at least one process characteristic comprises a temperature disttibution in the formation.
5259. The method of claim 5240, wherein at least one process characteristic comprises a heat input rate.
5260. The method ofclaim 5240, wherehi at least one property comprises a physical property of the foπnation.
5261. The method of claim 5240, wherein at least one property comprises richness of the foπnation.
5262. The method of claim 5240, wherein at least one property comprises a heat capacity.
5263. The method of claim 5240, wherein at least one property comprises a thermal conductivity.
5264. The method ofclaim 5240, wherein at least one property comprises a coefficient of thermal expansion.
5265. The method of claim 5240, wherein at least one property comprises a mechanical property.
5266. The method of claim 5240, wherein at least one property comprises an elastic modulus.
5267. The method ofclaim 5240, wherein at least one property comprises a Poisson's ratio.
5268. The method of claim 5240, wherein at least one property comprises cohesion sfress.
5269. The method of claim 5240, wherein at least one property comprises a friction angle.
5270. The method of claim 5240, wherein at least one property comprises a cap eccentricity.
5271. The method of claim 5240, wherein at least one property comprises a cap yield stress.
5272. The method of claim 5240, wherein at least one property comprises a cohesion creep multiplier.
5273. The method of claim 5240, wherein at least one property comprises a thermal expansion coefficient.
5274. A method of using a computer system for modeling an in situ process for treating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing to the computer system at least one set of operating conditions for the in situ process, wherein the process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation; providing to the computer system at least one desfred defonnation characteristic for the in situ process; and assessing at least one additional operating condition of the foπnation that achieves at least one desired deformation characteristic.
5275. The method of clahn 5274, further comprising operating the in situ system using at least one additional operating condition.
5276. The method ofclaim 5274, wherein the in situ process comprises two or more heat sources.
5277. The method ofclaim 5274, wherein the in situ process provides heat from one or more heat sources to at least one portion of the formation.
5278. The method ofclaim 5274, wherein the in situ process allows heat to fransfer from one or more heat sources to a selected section of the fonnation.
5279. The method ofclaim 5274, wherein at least one set of operating conditions comprises at least one set of pressures.
5280. The method ofclaim 5274, wherein at least one set of operating conditions comprises at least one set of temperatures.
5281. The method of claim 5274, wherein at least one set of operating conditions comprises at least one set of heating rates.
5282. The method ofclaim 5274, wherein at least one set of operating conditions comprises at least one set of overburden thicknesses.
5283. The method of claim 5274, wherein at least one set of operating conditions comprises at least one set of thicknesses of a treated portion of the formation.
5284. The method ofclaim 5274, wherein at least one set of operating conditions comprises at least one set of widths of a treated portion of the formation.
5285. The method ofclaim 5274, wherein at least one set of operating conditions comprises at least one set of radii of a freated portion of the foπnation.
5286. The method ofclaim 5274, wherein at least one desfred deformation characteristic comprises a selected subsidence.
5287. The method ofclaim 5274, wherein at least one desfred defonnation characteristic comprises a selected heave.
5288. The method ofclaim 5274, wherein at least one desired deformation characteristic comprises a selected compaction.
5289. The method of clahn 5274, wherein at least one desfred deformation characteristic comprises a selected shear deformation.
5290. A method of using a computer system for modeling an in situ process for treating a relatively low permeability fonnation containing heavy hydrocarbons, comprising: providing one or more values of at least one operating condition; assessing one or more values of at least one defonnation characteristic using a simulation method based on the one or more values of at least one operating condition; providing a desired value of at least one deformation characteristic for the in situ process to the computer system, wherein the process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and assessing a desired value of at least one operating condition that achieves the desired value of at least one deformation characteristic from the deteπnined values of at least one deformation characteristic and the provided values of at least one operating condition.
5291. The method ofclaim 5290, further comprising operating the in situ process using the desired value of at least one operating condition.
5292. The method ofclaim 5290, wherein the in situ process comprises two or more heat sources.
5293. The method of claim 5290, wherein at least one operating condition comprises a pressure.
5294. The method of claim 5290, wherein at least one operating condition comprises a heat input rate.
5295. The method of claim 5290, wherehi at least one operating condition comprises a temperature.
5296. The method ofclaim 5290, wherein at least one operating condition comprises a heating rate.
5297. The method ofclaim 5290, wherein at least one operating condition comprises an overburden thickness.
5298. The method ofclaim 5290, wherehi at least one operating condition comprises a thickness of a treated portion of the formation.
5299. The method ofclaim 5290, wherein at least one operating condition comprises a width of a treated portion of the foπnation.
5300. The method ofclaim 5290, wherein at least one operating condition comprises a radius of a treated portion of the formation.
5301. The method of claim 5290, wherein at least one deformation characteristic comprises subsidence.
5302. The method ofclaim 5290, wherein at least one deformation characteristic comprises heave.
5303. The method ofclaim 5290, wherein at least one deformation characteristic comprises compaction.
5304. The method ofclaim 5290, wherein at least one defonnation characteristic comprises shear defonnation.
5305. The method ofclaim 5290, wherein a value of at least one foimation characteristic comprises the formation characteristic as a function of time.
5306. The method of clahn 5290, further comprising deteπninhig a value of at least one defonnation characteristic based on the desfred value of at least one operating condition using the simulation method.
5307. The method ofclaim 5290, wherein deteπnining the desired value of at least one operating condition comprises inteφolating the desired value from the detennined values of at least one foimation characteristic and the provided values of at least one operating condition.
5308. A method of using a computer system for modeling an in situ process for treating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing a deshed value of at least one deformation characteristic for the in situ process to the computer system, wherein the in situ process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the foimation; and assessing a value of at least one operating condition to achieve the desired value of at least one deformation characteristic from a database in memory on the computer system comprising a relationship between at least one deformation characteristic and at least one operating condition for the in situ process.
5309. The method ofclaim 5308, further comprising operating the in situ system using the desired value of at least one operating condition.
5310. The method ofclaim 5308, wherein the in situ system comprises two or more heat sources.
5311. The method ofclaim 5308, wherein the relationship is determined from one or more simulations of the in situ process using a simulation method.
5312. The method ofclaim 5308, wherein the relationship comprises one or more values of at least one deformation characteristic and conesponding values of at least one operating condition.
5313. The method of claim 5308, wherein the relationship comprises an analytical function.
5314. The method ofclaim 5308, wherein determining a value of at least one operating condition comprises inteφolating a value of at least one operating condition from the relationship.
5315. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a relatively low permeability foπnation containing heavy hydrocarbons, the method comprising: providing at least one property of the formation to a computer system; providing at least one operating condition to the computer system; determining at least one process characteristic of the in situ process, wherein the process comprises providing heat from one or more heat sources to at least one portion of the foimation, and wherehi the process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and determining at least one deformation characteristic of the formation using a simulation method from at least one property, at least one operating condition, and at least one process characteristic.
5316. A canier medium comprising program instructions, wherein the program instructions are computer- executable to implement a method comprishig: providing at least one property of the formation to a computer system; providing at least one operating condition to the computer system; determining at least one process characteristic of the in situ process, wherein the process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heat sources to a selected section of the formation; and determining at least one deformation characteristic of the formation using a simulation method from at least one property, at least one operating condition, and at least one process characteristic.
5317. A system, comprising: a CPU; a data memory coupled to the CPU; and
a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a relatively low permeability formation containing heavy hydrocarbons, the method comprising: providing to the computer system at least one set of operating conditions for the in situ process, wherein the process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the process comprises aUowing the heat to fransfer from the one or more heat sources to a selected section of the formation; providing to the computer system at least one desired deformation characteristic for the in situ process; and determining at least one additional operating condition of the formation that achieves at least one desired deformation characteristic.
5318. A canier medium comprising program instructions, wherein the program instractions are computer- executable to implement a method comprising: providing to the computer system at least one set of operating conditions for the in situ process, wherein the process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; providing to the computer system at least one desired deformation characteristic for the in situ process; and determhiing at least one additional operating condition of the foimation that achieves at least one desfred deformation characteristic.
5319. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a relatively low permeability foimation containing heavy hydrocarbons, the method comprising: providing one or more values of at least one operating condition; deteπnining one or more values of at least one defonnation characteristic using a shnulation method based on the one or more values of at least one operating condition; providing a desfred value of at least one defonnation characteristic for the in situ process to the computer system,' wherein the process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the process comprises aUowing the heat to transfer from the one or more heat sources to a selected section of the formation; and determining a desired value of at least one operating condition that achieves the desired value of at least one defonnation characteristic from the determined values of at least one defonnation characteristic and the provided values of at least one operating condition.
5320. A canier medium comprising program instructions, wherein the program instructions are computer- executable to implement a method comprising: providing one or more values of at least one operating condition; deteπnining one or more values of at least one defonnation characteristic using a simulation method based on the one or more values of at least one operating condition; providing a desired value of at least one defonnation characteristic for the in situ process to the computer system, wherein the process comprises providing heat from one or more heat sources to at least one portion of the foimation, and wherein the process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and determining a desired value of at least one operating condition that achieves the desired value of at least one defonnation characteristic from the determined values of at least one defonnation characteristic and the provided values of at least one operating condition.
5321. A system, comprising: a CPU; a data memory coupled to the CPU; and a system memory coupled to the CPU, wherehi the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a relatively low permeability formation containing heavy hydrocarbons, the method comprising: providing a desfred value of at least one deformation characteristic for the in situ process to the computer system, wherein the process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and determining a value of at least one operating condition to achieve the desired value of at least one deformation characteristic from a database in memory on the computer system comprising a relationship between at least one formation characteristic and at least one operating condition for the in situ process.
5322. A canier medium comprising program instractions, wherein the program instructions are computer- executable to implement a method comprising: providing a desfred value of at least one deformation characteristic for the in situ process to the computer system, wherein the process comprises providing heat from one or more heat sources to at least one portion of the formation, and wherein the process comprises allowing the heat to fransfer from the one or more heat sources to a selected section of the foπnation; and determining a value of at least one operating condition to achieve the desired value of at least one deformation characteristic from a database in memory on the computer system comprising a relationship between at least one formation characteristic and at least one operating condition for the in situ process.
5323. A system configurable to provide heat to a relatively low permeability formation containing heavy hydrocarbons, comprising:
a first oxidizer configurable to be placed in an opening in the foπnation, wherein the first oxidizer is configurable to oxidize a first fuel during use; a second oxidizer configurable to be placed in the opening, wherein the second oxidizer is configurable to oxidize a second fuel during use; and wherein the system is configurable to allow heat from oxidation of the first fuel or the second fuel to fransfer to the foπnation during use.
5324. The system ofclaim 5323, wherein the system is configured to provide heat to the relatively low permeability formation containing heavy hydrocarbons.
5325. The system ofclaim 5323, wherein the first oxidizer is configured to be placed in an opening in the formation and wherein the ffrst oxidizer is configured to oxidize the first fuel during use.
5326. The system ofclaim 5323, wherein the second oxidizer is configured to be placed in the opening and wherein the second oxidizer is configured to oxidize the second fuel during use.
5327. The system of claim 5323, wherein the system is configured to allow the heat from the oxidation to ttansfer to the formation during use.
5328. The system of claim 5323, wherein the first oxidizer comprises a burner.
5329. The system of claim 5323, wherein the first oxidizer comprises an inline burner.
5330. The system ofclaim 5323, wherein the second oxidizer comprises a burner.
5331. The system ofclaim 5323, wherein the second oxidizer comprises a ring burner.
5332. The system ofclaim 5323, wherein a distance between the first oxidizer and the second oxidizer is less than about 250 meters.
5333. The system ofclaim 5323, further comprising a conduit configurable to be placed in the opening.
5334. The system ofclaim 5323, further comprising a conduit configurable to be placed in the opening, wherein the conduit is configurable to provide an oxidizing fluid to the first oxidizer during use.
5335. The system ofclaim 5323, further comprising a conduit configurable to be placed in the opening, wherein the conduit is configurable to provide the first fuel to the first oxidizer during use.
5336. The system ofclaim 5323, further comprising a conduit configurable to be placed in the opening, wherein the conduit is configurable to provide an oxidizhig fluid to the second oxidizer during use.
5337. The system ofclaim 5323, further comprising a conduit configurable to be placed in the opening, wherein the conduit is configurable to provide the second fuel to the second oxidizer during use.
5338. The system ofclaim 5323, further comprising a thfrd oxidizer configurable to be placed in the opening, wherein the thfrd oxidizer is configurable to oxidize a third fuel during use.
5339. The system ofclaim 5323, further comprising a fuel source, wherein the fuel source is configurable to provide the ffrst fuel to the first oxidizer or the second fuel to the second oxidizer during use.
5340. The system ofclaim 5323, wherein the first fuel is different from the second fuel.
5341. The system ofclaim 5323, wherein the ffrst fuel is different from the second fuel, wherein the second fuel comprises hydrogen.
5342. The system ofclaim 5323, wherein a flow of the first fuel is separately confrolled from a flow of the second fuel.
5343. The system of claim 5323, wherein the first oxidizer is configurable to be placed proximate an upper portion of the opening.
5344. The system ofclaim 5323, wherein the second oxidizer is configurable to be placed proximate a lower portion of the opening.
5345. The system ofclaim 5323, further comprising insulation configurable to be placed proximate the first oxidizer.
5346. The system ofclaim 5323, further comprising insulation configurable to be placed proxhnate the second oxidizer.
5347. The system ofclaim 5323, wherehi products from oxidation of the first fuel or the second fuel are removed from the formation through the opening during use.
5348. The system ofclaim 5323, further comprising an exhaust conduit configurable to be coupled to the opening to allow exhaust fluid to flow from the formation through the exhaust conduit during use.
5349. The system ofclaim 5323, wherein the system is configured to allow the heat from the oxidation of the first fuel or the second fuel to fransfer to the foimation during use.
5350. The system of claim 5323, wherein the system is configured to allow the heat from the oxidation to fransfer to a pyrolysis zone in the formation during use.
5351. The system ofclaim 5323, wherehi the system is configured to allow the heat from the oxidation to fransfer to a pyrolysis zone in the foπnation during use, and wherein the fransfened heat causes pyrolysis of at least some hydrocarbons in the pyrolysis zone during use.
5352. The system ofclaim 5323, wherein at least some of the heat from the oxidation is generated at the ffrst oxidizer.
5353. The system ofclaim 5323, wherein at least some of the heat from the oxidation is generated at the second oxidizer
5354. The system ofclaim 5323, wherein a combination of heat from the first oxidizer and heat from the second oxidizer substantially uniformly heats a portion of the foimation during use.
5355. The system ofclaim 5323, further comprising a first conduit configurable to be placed in the opening of the formation, wherein the first conduit is configurable to provide a first oxidizing fluid to the first oxidizer in the opening during use, and wherein the first conduit is further configurable to provide a second oxidizing fluid to the second oxidizer in the opening during use.
5356. The system ofclaim 5355, further comprising a fuel conduit configurable to be placed in the opening, wherein the fuel conduit is further configurable to provide the ffrst fuel to the first oxidizer during use.
5357. The system ofclaim 5356, wherein the fuel conduit is further configurable to be placed in the first conduit.
5358. The system ofclaim 5356, wherein the first conduit is further configurable to be placed in the fuel conduit.
5359. The system ofclaim 5355, further comprising a fuel conduit configurable to be placed in the openhig, wherein the fuel conduit is further configurable to provide the second fuel to the second oxidizer during use.
5360. The system ofclaim 5355, wherein the first conduit is further configurable to provide the first fuel to the first oxidizer during use.
5361. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising:
providing a ffrst oxidizing fluid to a first oxidizer placed in an opening in the foπnation; providing a first fuel to the first oxidizer; oxidizing at least some of the ffrst fuel in the first oxidizer; providing a second oxidizing fluid to a second oxidizer placed in the opening in the formation; providing a second fuel to the second oxidizer; oxidizing at least some of the second fuel in the second oxidizer; and allowing heat from oxidation of the first fuel and the second fuel to fransfer to a portion of the formation.
5362. The method ofclaim 5361, wherein the ffrst oxidizing fluid is provided to the first oxidizer through a conduit placed in the openhig.
5363. The method ofclaim 5361, wherein the second oxidizing fluid is provided to the second oxidizer through a conduit placed in the opening.
5364. The method of claim 5361, wherein the ffrst fuel is provided to the first oxidizer through a conduit placed in the opening.
5365. The method of clahn 5361, wherein the first fuel is provided to the second oxidizer through a conduit placed in the opening.
5366. The method ofclaim 5361, wherein the first oxidizing fluid and the first fuel are provided to the first oxidizer through a conduit placed in the opening.
5367. The method ofclaim 5361, further comprising using exhaust fluid from the first oxidizer as a portion of the second fuel used in the second oxidizer.
5368. The method ofclaim 5361, further comprising allowing the heat to fransfer substantially by conduction from the portion of the formation to a pyrolysis zone of the formation.
5369. The method ofclaim 5361, further comprising initiating oxidation of the second fuel in the second oxidizer with an ignition source.
5370. The method of claim 5361, further comprising removing exhaust fluids through the opening.
5371. The method of claim 5361, further comprismg removing exhaust fluids through the opening, wherein the exhaust fluids comprise heat and allowing at least some heat in the exhaust fluids to ttansfer from the exhaust fluids to the ffrst oxidizing fluid prior to oxidation in the first oxidizer.
5372. The method ofclaim 5361, further comprising removing exhaust fluids comprising heat through the opening, allowing at least some heat in the exhaust fluids to transfer from the exhaust fluids to the ffrst oxidizing fluid prior to oxidation, and increasing a thermal efficiency of heathig the relatively low permeability formation containing heavy hydrocarbons.
5373. The method ofclaim 5361, further comprising removing exhaust fluids through an exhaust conduit coupled to the opening.
5374. The method of claim 5361, further comprising removing exhaust fluids tiirough an exhaust conduit coupled to the opening and providing at least a portion of the exhaust fluids to a fourth oxidizer to be used as a fourth fuel in a fourth oxidizer, wherein the fourth oxidizer is located in a separate opening in the formation.
5375. A system configurable to provide heat to a relatively low permeability formation containing heavy hydrocarbons, comprising: an opening placed in the fonnation, wherein the opening comprises a first elongated portion, a second elongated portion, and a third elongated portion, wherein the second elongated portion diverges from the first elongated portion in a first direction, wherein the thfrd elongated portion diverges from the first elongated portion in a second dfrection, and wherein the first direction is substantially different than the second direction; a ffrst heater configurable to be placed in the second elongated portion, wherein the first heater is configurable to heat at least a portion of the formation during use; a second heater configurable to be placed in the third elongated portion, wherein the second heater is configurable to heat to at least a portion of the formation during use; and wherein the system is configurable to allow heat to ttansfer to the formation during use.
5376. The system ofclaim 5375, wherein the first heater and the second heater are configurable to heat to at least a portion of the foimation during use.
5377. The system ofclaim 5375, wherein the second and the third elongated portions are oriented substantially horizontally within the formation.
5378. The system ofclaim 5375, wherein the first dfrection is about 180° opposite the second dfrection.
5379. The system ofclaim 5375, wherein the first elongated portion is placed substantially within an overburden of the formation.
5380. The system of claim 5375, wherein the fransfened heat substantially uniformly heats a portion of the fonnation during use.
5381. The system of claim 5375, wherein the first heater or the second heater comprises a downhole combustor.
5382. The system of claim 5375, wherein the first heater or the second heater comprises an insulated conductor heater.
5383. The system ofclaim 5375, wherein the first heater or the second heater comprises a conductor-in-conduit heater.
5384. The system ofclaim 5375, wherein the first heater or the second heater comprises an elongated member heater.
5385. The system ofclaim 5375, wherein the first heater or the second heater comprises a natural disfributed combustor heater.
5386. The system ofclaim 5375, wherein the first heater or the second heater comprises a flameless disfributed combustor heater.
5387. The system of claim 5375, wherein the first heater comprises a first oxidizer and the second heater comprises a second oxidizer.
5388. The system ofclaim 5387, wherein the second elongated portion has a length of less than about 175 meters.
5389. The system ofclaim 5387, wherein the third elongated portion has a length of less than about 175 meters.
5390. The system of clahn 5387, further comprising a fuel conduit configurable to be placed in the opening, wherein the fuel conduit is further configurable to provide fuel to the first oxidizer during use.
5391. The system of claim 5387, further comprising a fuel conduit configurable to be placed in the opening, wherein the fuel conduit is further configurable to provide fuel to the second oxidizer during use.
5392. The system ofclaim 5387, further comprising a fuel source, wherein the fuel source is configurable to provide fuel to the first oxidizer or the second oxidizer during use.
5393. The system of claim 5387, further comprising a thfrd oxidizer placed within the first elongated portion of the opening.
5394. The system ofclaim 5393, further comprising a fuel conduit configurable to be placed in the opening, wherein the fuel conduit is further configurable to provide fuel to the third oxidizer during use.
5395. The system ofclaim 5393, further comprising a first fuel source configurable to provide a first fuel to the first fuel conduit, a second fuel source configurable to provide a second fuel to a second fuel conduit, and a third fuel source configurable to provide a thfrd fuel to a third fuel conduit.
5396. The system ofclaim 5395, wherein the first fuel has a composition substantiaUy different from the second fuel or the third fuel.
5397. The system ofclaim 5375, further comprising insulation configurable to be placed proximate the first heater.
5398. The system ofclaim 5375, further comprising insulation configurable to be placed proximate the second heater.
5399. The system of clahn 5375, wherein a fuel is oxidized in the first heater or the second heater to generate heat and wherein products from oxidation are removed from the foimation through the opening during use.
5400. The system ofclaim 5375, wherein a fuel is oxidized in the ffrst heater and the second heater and wherein products from oxidation are removed from the formation through the opening during use.
5401. The system ofclaim 5375, further comprising an exhaust conduit configurable to be coupled to the opening to allow exhaust fluid to flow from the formation through the exhaust conduit during use.
5402. The system ofclaim 5387, wherein the system is configured to allow the heat from oxidation of fuel to fransfer to the foimation during use.
5403. The system of claim 5375, wherein the system is configured to allow heat to fransfer to a pyrolysis zone in the formation during use.
5404. The system ofclaim 5375, wherein the system is configured to allow heat to fransfer to a pyrolysis zone in the formation during use, and wherein the transfened heat causes pyrolysis of at least some hydrocarbons within the pyrolysis zone during use.
5405. The system of claim 5375, wherehi a combination of the heat generated from the first heater and the heat generated from the second heater substantially uniformly heats a portion of the foimation during use.
5406. The system ofclaim 5375, further comprising a thfrd heater placed in the second elongated portion.
5407. The system ofclaim 5406, wherein the third heater comprises a downhole combustor.
5408. The system of claim 5406, further comprising a fourth heater placed in the third elongated portion.
5409. The system ofclaim 5408, wherein the fourth heater comprises a downhole combustor.
5410. The system ofclaim 5375, wherein the first heater is configured to be placed in the second elongated portion, wherein the first heater is configured to provide heat to at least a portion of the formation during use, wherein the second heater is configured to be placed in the thfrd elongated portion, wherehi the second heater is configured to provide heat to at least a portion of the formation during use, and wherein the system is configured to allow heat to fransfer to the formation during use.
5411. The system ofclaim 5375, wherein the second and the thfrd elongated portions are located in a substantially similar plane.
5412. The system ofclaim 5411, wherein the opening comprises a fourth elongated portion and a fifth elongated portion, wherein the fourth elongated portion diverges from the first elongated portion in a thhd dfrection, wherein the fifth elongated portion diverges from the first elongated portion in a fourth direction, and wherein the third direction is substantially different than the fourth direction.
5413. The system ofclaim 5412, wherein the fourth and fifth elongated portions are located in a plane substantially different than the second and the thfrd elongated portions.
5414. The system ofclaim 5412, wherein a third heater is configurable to be placed in the fourth elongated portion, and wherein a fourth heater is configurable to be placed in the fifth elongated portion.
5415. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat from two or more heaters placed in an opening in the formation, wherehi the opening comprises a ffrst elongated portion, a second elongated portion, and a third elongated portion, wherein the second elongated portion diverges from the first elongated portion in a first direction, wherein the third elongated portion diverges from the first elongated portion in a second direction, and wherein the first dfrection is substantially different than the second direction; allowing heat from the two or more heaters to transfer to a portion of the formation; and wherein the two or more heaters comprise a first heater placed in the second elongated portion and a second heater placed in the thfrd elongated portion.
5416. The method of claim 5415, wherein the second and the third elongated portions are oriented substantially horizontally within the formation.
5417. The method of clahn 5415, wherein the first elongated portion is located substantially within an overburden of the formation.
5418. The method ofclaim 5415, further comprising substantially uniformly heating a portion of the formation.
5419. The method of claim 5415, wherein the first heater or the second heater comprises a downhole combustor.
5420. The method ofclaim 5415, wherein the first heater or the second heater comprises an insulated conductor heater.
5421. The method of claim 5415, wherein the ffrst heater or the second heater comprises a conductor-in-conduit heater.
5422. The method ofclaim 5415, wherein the ffrst heater or the second heater comprises an elongated member heater.
5423. The method of claim 5415, wherein the ffrst heater or the second heater comprises a natural disfributed combustor heater.
5424. The method ofclaim 5415, wherein the first heater or the second heater comprises a flameless distributed combustor heater.
5425. The method ofclaim 5415, wherein the first heater comprises a first oxidizer and the second heater comprises a second oxidizer.
5426. The method ofclaim 5415, wherein the first heater comprises a ffrst oxidizer and the second heater comprises a second oxidizer and further comprising providing fuel to the ffrst oxidizer through a fuel conduit placed in the opening.
5427. The method ofclaim 5415, wherein the ffrst heater comprises a first oxidizer and the second heater comprises a second oxidizer and further comprising providing fuel to the second oxidizer through a fuel conduit placed in the opening.
5428. The method ofclaim 5415, wherein the two or more heaters comprise oxidizers and further comprising providing fuel to the oxidizers from a fuel source.
5429. The method of claim 5425, further comprising providing heat to a portion of the formation using a third oxidizer placed within the ffrst elongated portion of the opening.
5430. The method ofclaim 5415, wherein the ffrst heater comprises a first oxidizer and the second heater comprises a second oxidizer further comprising:
providing heat to a portion of the formation using a third oxidizer placed within the ffrst elongated portion of the opening; and providing fuel to the third oxidizer through a fuel conduit placed in the opening.
5431. The method of claim 5415, wherein the two or more heaters comprise oxidizers, and further comprising providing heat by oxidizing a fuel within the oxidizers and removing products of oxidation of fuel through the opening.
5432. The method ofclaim 5415, wherein the two or more heaters comprise oxidizers, and further comprising removing products from oxidation of fuel through an exhaust conduit coupled to the opening.
5433. The method ofclaim 5415, further comprising allowing the heat to ttansfer from the portion to a pyrolysis zone in the formation.
5434. The method of claim 5415, further comprising allowing the heat to ttansfer from the portion to a pyrolysis zone in the formation and pyrolyzing at least some hydrocarbons within the pyrolysis zone with the fransfened heat.
5435. The method ofclaim 5415, further comprising allowing the heat to ttansfer to from the portion to a pyrolysis zone in the formation, pyrolyzing at least some hydrocarbons within the pyrolysis zone with the transfened heat, and producing a portion of the pyrolyzed hydrocarbons through a conduit placed in the first elongated portion.
5436. The method ofclaim 5415, further comprising providing heat to a portion of the formation using a thfrd heater placed in the second elongated portion.
5437. The method of claim 5436, wherein the third heater comprises a downhole combustor.
5438. The method of claim 5436, further comprising providing heat to a portion of the formation using a fourth heater placed in the thfrd elongated portion.
5439. The method ofclaim 5438, wherein the fourth heater comprises a downhole combustor.
5440. A system configurable to provide heat to a relatively low permeability formation containing heavy hydrocarbons, comprising: an oxidizer configurable to be placed in an opening in the formation, wherein the oxidizer is configurable to oxidize fuel to generate heat during use; a first conduit configurable to be placed in the opening of the foπnation, wherein the first conduit is configurable to provide oxidizing fluid to the oxidizer in the opening during use; a heater configurable to be placed in the opening and configurable to provide additional heat; and
wherein the system is configurable to allow the generated heat and the additional heat to ttansfer to the foπnation during use.
5441. The system of claim 5440, wherein the heater comprises an insulated conductor.
5442. The system of claim 5440, wherein the heater comprises a conductor-in-conduit heater.
5443. The system ofclaim 5440, wherein the heater comprises an elongated member heater.
5444. The system ofclaim 5440, wherein the heater comprises a flameless disfributed combustor.
5445. The system ofclaim 5440, wherein the oxidizer is configurable to be placed proximate an upper portion of the opening.
5446. The system ofclaim 5440, further comprising insulation configurable to be placed proximate the oxidizer.
5447. The system of claim 5440, wherein the heater is configurable to be coupled" to the first conduit.
5448. The system ofclaim 5440, wherein products from the oxidation of the fuel are removed from the formation through the opening during use.
5449. The system of claim 5440, further comprising an exhaust conduit configurable to be coupled to the opening to allow exhaust fluid to flow from the formation through the exhaust conduit during use.
5450. The system ofclaim 5440, wherein the system is configured to allow the generated heat and the additional heat to fransfer to the foimation during use.
5451. The system of claim 5440, wherein the system is configured to allow the generated heat and the additional heat to transfer to a pyrolysis zone in the formation during use.
5452. The system of claim 5440, wherein the system is configured to allow the generated heat and the additional heat to ttansfer to a pyrolysis zone in the formation during use, and wherein the fransfened heat pyrolyzes of at least some hydrocarbons within the pyrolysis zone during use.
5453. The system ofclaim 5440, wherehi a combination of the generate heat and the additional heat substantially uniformly heats a portion of the formation during use.
5454. The system of claim 5440, wherein the oxidizer is configured to be placed in the opening in the formation and wherein the oxidizer is configured to oxidize at least some fuel during use.
5455. The system ofclaim 5440, wherein the first conduit is configured to be placed in the opening of the formation and wherein the ffrst conduit is configured to provide oxidizing fluid to the oxidizer in the opening during use.
5456. The system of claim 5440, wherein the heater is configured to be placed in the opening and wherein the heater is configurable to provide heat to a portion of the foπnation during use
5457. The system ofclaim 5440, wherein the system is configured to allow the heat from the oxidation of at least some fuel and from the heater to fransfer to the formation during use.
5458. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: allowing heat to fransfer from a heater placed in an opening to a portion of the formation. providing oxidizing fluid to an oxidizer placed in the opening in the formation; providing fuel to the oxidizer; oxidizing at least some fuel in the oxidizer; and allowing additional heat from oxidation of at least some fuel to fransfer to the portion of the foimation.
5459. The method ofclaim 5458, wherein the heater comprises an insulated conductor.
5460. The method of claim 5458, wherein the heater comprises a conductor-in-conduit heater.
5461. The method ofclaim 5458, wherein the heater comprises an elongated member heater.
5462. The method ofclaim 5458, wherein the heater comprises a flameless disfributed combustor.
5463. The method of claim 5458, wherein the oxidizer is placed proximate an upper portion of the opening.
5464. The method ofclaim 5458, further comprising allowing the additional heat to transfer from the portion to a pyrolysis zone in the formation.
5465. The method of clahn 5458, further comprising allowing the additional heat to fransfer from the portion to a pyrolysis zone in the foπnation and pyrolyzing at least some hydrocarbons within the pyrolysis zone.
5466. The method ofclaim 5458, further comprising substantially uniformly heating the portion of the formation.
5467. The method ofclaim 5458, further comprising removing exhaust fluids through the opening.
5468. The method ofclaim 5458, further comprising removing exhaust fluids through an exhaust annulus in the formation.
5469. The method ofclaim 5458, further comprising removing exhaust fluids through an exhaust conduit coupled to the opening.
5470. A system configurable to provide heat to a relatively low peπneability foπnation containing heavy hydrocarbons, comprising: a heater conflgurable to be placed in an opening in the formation, wherein the heater is configurable to heat a portion of the formation to a temperature sufficient to sustain oxidation of hydrocarbons during use; an oxidizing fluid source configurable to provide an oxidizing fluid to a reaction zone of the formation to oxidize at least some hydrocarbons in the reaction zone during use such that heat is generated in the reaction zone, and wherein at least some of the reaction zone has been previously heated by the heater; a ffrst conduit configurable to be placed in the opening, wherein the first conduit is configurable to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use, wherein the flow of oxidizing fluid can be controlled along at least a segment of the first conduit; and wherein the system is configurable to allow the generated heat to transfer from the reaction zone to the formation during use.
5471. The system of claim 5470, wherein the system is configurable to provide hydrogen to the reaction zone during use.
5472. The system ofclaim 5470, wherein the oxidizing fluid is transported through the reaction zone substantiaUy by diffusion.
5473. The system of claim 5470, wherein the system is configurable to allow the generated heat to ttansfer from the reaction zone to a pyrolysis zone in the foπnation during use.
5474. The system of claim 5470, wherein the system is conflgurable to allow the generated heat to transfer substantially by conduction from the reaction zone to the formation during use.
5475. The system ofclaim 5470, wherein a temperature within the reaction zone can be controlled along at least a segment of the first conduit during use.
5476. The system of claim 5470, wherein a heating rate in at least a section of the formation proximate at least a segment of the first conduit be confrolled.
5477. The system of claim 5470, wherein the oxidizing fluid is configurable to be transported through the reaction zone substantially by diffusion, and wherein a rate of diffusion of the oxidizing fluid can controlled by a temperature within the reaction zone.
5478. The system ofclaim 5470, wherein the first conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening during use.
5479. The system of claim 5470, wherehi the ffrst conduit comprises critical flow orifices, and wherein the critical flow orifices are positioned on the first conduit such that a flow rate of the oxidizing fluid is confrolled at a selected rate during use.
5480. The system ofclaim 5470, further comprising a second conduit configurable to remove an oxidation product during use.
5481. The system of claim 5480, wherein the second conduit is further configurable to allow heat within the oxidation product to ttansfer to the oxidizing fluid in the first conduit during use.
5482. The system ofclaim 5480, wherein a pressure of the oxidizing fluid in the first conduit and a pressure of the oxidation product in the second conduit are controlled during use such that a concentration of the oxidizing fluid along the length of the first conduit is substantiaUy uniform.
5483. The system ofclaim 5480, wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone during use.
5484. The system ofclaim 5470, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the foimation beyond the reaction zone during use.
5485. The system ofclaim 5470, wherein the portion of the formation extends radially from the opening a distance of less than approxhnately 3 m.
5486. The system ofclaim 5470, wherein the reaction zone extends radially from the opening a distance of less than approximately 3 m.
5487. The system ofclaim 5470, wherehi the system is configurable to pyrolyze at least some hydrocarbons in a pyrolysis zone of the formation.
5488. The system ofclaim 5470, wherein the heater is configured to be placed in an opening in the formation and wherein the heater is configured to provide the heat to at least the portion of the formation during use.
5489. The system ofclaim 5470, wherein a first conduit is configured to be placed in the opening and wherein the first conduit is configured to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use.
5490. The system ofclaim 5470, wherein the flow of oxidizing fluid is confrolled along at least a segment of the length of the ffrst conduit and wherein the system is configured to allow the additional heat to fransfer from the reaction zone to the formation during use.
5491. An in situ method for providing heat to a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons with an oxidizing fluid within the portion of the foimation; providing the oxidizing fluid to a reaction zone in the foπnation; confrolling a flow of the oxidizing fluid along at least a length of the reaction zone; generating heat within the reaction zone; and allowing the generated heat to transfer to the formation.
5492. The method ofclaim 5491, further comprising allowing the oxidizing fluid to react with at least some of the hydrocarbons in the reaction zone to generate the heat in the reaction zone.
5493. The method ofclaim 5491, wherein at least a section of the reaction zone is proximate an opening in the formation.
5494. The method ofclaim 5491, further comprising fransporting the oxidizing fluid through the reaction zone substantially by diffusion.
5495. The method of claim 5491 , further comprising transporting the oxidizing fluid through the reaction zone substantially by diffusion, and confrolling a rate of diffusions of the oxidizing fluid by controlling a temperature within the reaction zone.
5496. The method ofclaim 5491, wherein the generated heat fransfers from the reaction zone to a pyrolysis zone in the formation.
5497. The method of claim 5491 , wherein the generated heat transfers from the reaction zone to the foimation substantially by conduction.
5498. The method ofclaim 5491, further comprismg controlling a temperature along at least a length of the reaction zone.
5499. The method ofclaim 5491, further comprising controlling a flow of the oxidizing fluid along at least a length of the reaction zone, and controlling a temperature along at least a length of the reaction zone.
5500. The method ofclaim 5491, further comprising controlling a heating rate along at least a length of the reaction zone.
5501. The method of claim 5491, wherein the oxidizing fluid is provided through a conduit placed within an opening in the formation, wherein the conduit comprises orifices.
5502. The method of claim 5491, further comprising confrolling a rate of oxidation by providing the oxidizing fluid to the reaction zone from a conduit having critical flow orifices.
5503. The method ofclaim 5491, wherein the oxidizing fluid is provided to the reaction zone through a conduit placed within the foimation, and further comprising positioning critical flow orifices on the conduit such that the flow rate of the oxidizhig fluid to at least a length of the reaction zone is controlled at a selected flow rate.
5504. The method ofclaim 5491, wherein the oxidizing fluid is provided to the reaction zone from a conduit placed within an opening in the foimation, and further comprising sizing critical flow orifices on the conduit such that the flow rate of the oxidizing fluid to at least a length of the reaction zone is controlled at a selected flow rate.
5505. The method of claim 5491 , further comprising increasing a volume of the reaction zone, and increasing the flow of the oxidizing fluid to the reaction zone such that a rate of oxidation within the reaction zone is substantially constant over time.
5506. The method ofclaim 5491, further comprismg maintaining a substantially constant rate of oxidation within the reaction zone over time.
5507. The method ofclaim 5491, wherein a conduit is placed in an opening in the formation, and further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.
5508. The method ofclaim 5491, further comprising removing an oxidation product from the formation through a conduit placed in an opening in the formation.
5509. The method ofclaim 5491, further comprising removing an oxidation product from the formation through a conduit placed in an opening in the formation and substantially inhibiting the oxidation product from flowing into a sunounding portion of the foimation.
5510. The method of claim 5491 , ftirther comprising inhibiting the oxidizing fluid from flowing into a sunounding portion of the formation.
5511. The method of claim 5491 , further comprising removing at least some water from the formation prior to heating the portion.
5512. The method of claim 5491, further comprising providing additional heat to the formation from an elecfric heater placed in the opening.
5513. The method of claim 5491 , further comprising providing additional heat to the formation from an electric heater placed in an opening in the formation such that the oxidizing fluid continuously oxidizes at least a portion of the hydrocarbons in the reaction zone.
5514. The method of claim 5491 , further comprising providing additional heat to the formation from an elecfric heater placed in the opening to maintain a constant heat rate in the formation.
5515. The method of claim 5514, further comprising providing elecfricity to the elecfric heater using a wind powered device.
5516. The method of claim 5514, further comprising providing electticity to the elecfric heater using a solar powered device.
5517. The method of claim 5491 , further comprising maintaining a temperature within the portion above about the temperature sufficient to support the reaction of hydrocarbons with the oxidizing fluid.
5518. The method ofclaim 5491, further comprising providing additional heat to the formation from an electric heater placed in the opening and controlling the additional heat such that a temperature of the portion is greater than about the temperature sufficient to support the reaction of hydrocarbons with the oxidizing fluid.
5519. The method of claim 5491 , further comprising removing oxidation products from the formation, and generating electticity using oxidation products removed from the formation.
5520. The method ofclaim 5491, further comprising removing oxidation products from the formation, and using at least some of the removed oxidation products in an afr compressor.
5521. The method ofclaim 5491, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone over time.
5522. The method ofclaim 5491, further comprising assessing a temperature in or proximate an opening in the foπnation, wherein the flow of oxidizing fluid along at least a section of the reaction zone is confrolled as a function of the assessed temperature.
5523. The method ofclaim 5491, further comprising assessing a temperature in or proximate an opening in the formation, and increasing the flow of oxidizing fluid as the assessed temperature decreases.
5524. The method ofclaim 5491, further comprising controlling the flow of oxidizing fluid to maintain a temperature in or proximate an opening in the formation at a temperature less than a pre-selected temperature.
5525. A system configurable to provide heat to a relatively low permeability formation containing heavy hydrocarbons, comprising: a heater configurable to be placed in an opening in the formation, wherein the heater is configurable to provide heat to at least a portion of the formation during use; an oxidizing fluid source conflgurable to provide an oxidizing fluid to a reaction zone of the foimation to generate heat in the reaction zone during use, wherein at least a portion of the reaction zone has been previously heated by the heater during use; a conduit configurable to be placed in the opening, wherein the conduit is configurable to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use; wherein the system is configurable to provide molecular hydrogen to the reaction zone during use; and wherein the system is configurable to allow the generated heat to transfer from the reaction zone to the formation during use.
5526. The system ofclaim 5525, wherein the system is configurable to allow the oxidizing fluid to be transported through the reaction zone substantially by diffusion during use.
5527. The system of claim 5525, wherein the system is configurable to allow the generated heat to ttansfer from the reaction zone to a pyrolysis zone in the foimation during use.
5528. The system ofclaim 5525, wherein the system is configurable to allow the generated heat to fransfer substantially by conduction from the reaction zone to the formation during use.
5529. The system ofclaim 5525, wherein the flow of oxidizing fluid can be controlled along at least a segment of the conduit such that a temperature can be confrolled along at least a segment of the conduit during use.
5530. The system ofclaim 5525, wherein a flow of oxidizing fluid can be confrolled along at least a segment of the conduit such that a heating rate in at least a section of the foπnation can be controlled.
5531. The system ofclaim 5525, wherein the oxidizhig fluid is configurable to move through the reaction zone substantiaUy by diffusion during use, wherein a rate of diffusion can confrolled by a temperature of the reaction zone.
5532. The system of claim 5525, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening during use.
5533. The system ofclaim 5525, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled during use.
5534. The system of claim 5525, wherein the conduit comprises a ffrst conduit and a second conduit, wherein the second conduit is configurable to remove an oxidation product during use.
5535. The system ofclaim 5525, wherein the oxidizing fluid is substantially inhibited from flowing from the reaction zone into a sunounding portion of the formation.
5536. The system ofclaim 5525, wherein at least the portion of the foimation extends radially from the opening a distance of less than approximately 3 m.
5537. The system ofclaim 5525, wherein the reaction zone extends radially from the opening a distance of less than approximately 3 m.
5538. The system of clahn 5525, wherein the system is conflgurable to allow transfened heat to pyrolyze at least some hydrocarbons in a pyrolysis zone of the foimation.
5539. The system ofclaim 5525, wherein the heater is configured to be placed in an opening in the foimation and wherein the heater is configured to provide heat to at least a portion of the foπnation during use.
5540. The system ofclaim 5525, wherein the conduit is configured to be placed in the openhig to provide at least some of the oxidizing fluid from the oxidizing fluid source to the reaction zone in the foimation during use, and wherein the flow of at least some of the oxidizing fluid can be controlled along at least a segment of the ffrst conduit.
5541. The system ofclaim 5525, wherein the system is configured to allow heat to fransfer from the reaction zone to the formation during use.
5542. The system ofclaim 5525, wherein the heater is configured to be placed in an opening in the formation and wherein the heater is configured to provide heat to at least a portion of the formation during use.
5543. The system of claim 5525, wherein the conduit is configured to be placed in the opening and wherein the conduit is configured to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use.
5544. The system of claim 5525, wherein the flow of oxidizing fluid can be controlled along at least a segment of the conduit.
5545. The system ofclaim 5525, wherein the system is configured to allow heat to transfer from the reaction zone to the fonnation during use.
5546. The system ofclaim 5525, wherein at least some of the provided hydrogen is produced in the pyrolysis zone during use.
5547. The system ofclaim 5525, wherein at least some of the provided hydrogen is produced in the reaction zone during use.
5548. The system of clahn 5525, wherein at least some of the provided hydrogen is produced in at least the heated portion of the formation during use.
5549. The system ofclaim 5525, wherein the system is configurable to provide hydrogen to the reaction zone during use such that production of carbon dioxide in the reaction zone is inhibited.
5550. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the fonnation with an oxidizing fluid; providing the oxidizing fluid to a reaction zone in the fonnation; allowing the oxidizing fluid to react with at least a portion of the hydrocarbons in the reaction zone to generate heat in the reaction zone; providing molecular hydrogen to the reaction zone; and transfening the generated heat from the reaction zone to a pyrolysis zone in the formation.
5551. The method ofclaim 5550, further comprising producing the molecular hydrogen in the pyrolysis zone.
5552. The method ofclaim 5550, further comprising producing the molecular hydrogen in the reaction zone.
5553. The method ofclaim 5550, .further comprising producing the molecular hydrogen in at least the heated portion of the formation.
5554. The method of claim 5550, further comprising inhibiting production of carbon dioxide in the reaction zone.
5555. The method ofclaim 5550, further comprising allowing the oxidizing fluid to fransfer through the reaction zone substantially by diffusion.
5556. The method of claim 5550, further comprising allowing the oxidizing fluid to fransfer through the reaction zone by diffusion, wherein a rate of diffusion is confrolled by a temperature of the reaction zone.
5557. The method ofclaim 5550, wherein at least some of the generated heat transfers to the pyrolysis zone substantially by conduction.
5558. The method ofclaim 5550, further comprising confrolling a flow of the oxidizing fluid along at least a segment reaction zone such that a temperature is controlled along at least a segment of the reaction zone.
5559. The method ofclaim 5550, further comprising controlling a flow of the oxidizing fluid along at least a segment of the reaction zone such that a heating rate is controlled along at least a segment of the reaction zone.
5560. The method of claim 5550, further comprising allowing at least some oxidizing fluid to flow into the formation through orifices in a conduit placed in an opening in the formation.
5561. The method ofclaim 5550, further comprising controlling a flow of the oxidizing fluid into the formation using critical flow orifices on a conduit placed in the opening such that a rate of oxidation is controlled.
5562. The method ofclaim 5550, further comprising controlling a flow of the oxidizing fluid into the formation with a spacing of critical flow orifices on a conduit placed in an opening in the formation.
5563. The method of clahn 5550, further comprising controlling a flow of the oxidizing fluid with a diameter of critical flow orifices in a conduit placed in an opening in the formation.
5564. The method of claim 5550, further comprising increasing a volume of the reaction zone, and increasing the flow of the oxidizing fluid to the reaction zone such that a rate of oxidation within the reaction zone is substantially constant over time
5565. The method of claim 5550, wherein a conduit is placed in an openhig in the foπnation, and further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.
5566. The method of claim 5550, further comprising removing an oxidation product from the foimation through a conduit placed in an opening in the formation.
5567. The method of claim 5550, further comprising removing an oxidation product from the foimation through a conduit placed in an opening in the formation and inhibiting the oxidation product from flowing into a sunounding portion of the formation beyond the reaction zone.
5568. The method ofclaim 5550, further comprising inhibiting the oxidizing fluid from flowing into a sunounding portion of the formation beyond the reaction zone.
5569. The method ofclaim 5550, further comprising removing at least some water from the formation prior to heating the portion.
5570. The method ofclaim 5550, further comprising providing additional heat to the foimation from an elecfric heater placed in the opening.
5571. The method ofclaim 5550, further comprising providing additional heat to the formation from an electric heater placed in the opening and continuously oxidizing at least a portion of the hydrocarbons in the reaction zone.
5572. The method ofclaim 5550, further comprising providing additional heat to the formation from an elecfric heater placed in an opening in the formation and maintaining a constant heat rate within the pyrolysis zone.
5573. The method of claim 5550, further comprising providing additional heat to the formation from an elecfric heater placed in the opening such that the oxidation of at least a portion of the hydrocarbons does not burn out.
5574. The method ofclaim 5550, further comprising removing oxidation products from the formation and generating elecfricity using at least some oxidation products removed from the formation.
5575. The method ofclaim 5550, further comprising removing oxidation products from the formation and using at least some oxidation products removed from the formation in an ah compressor.
5576. The method ofclaim 5550, further comprising increasing a flow of the oxidizing fluid in the reaction zone to accommodate an increase in a volume of the reaction zone over time.
5577. The method ofclaim 5550, further comprising increasing a volume of the reaction zone such that an amount of heat provided to the formation increases.
5578. The method ofclaim 5550, further comprising assessing a temperature in or proximate the opening, and controlling the flow of oxidizing fluid as a function of the assessed temperature.
5579. The method ofclaim 5550, further comprising assessing a temperature in or proximate the opening, and increasing the flow of oxidizing fluid as the assessed temperature decreases.
5580. The method ofclaim 5550, further comprising controlling the flow of oxidizing fluid to maintain a temperature in or proximate the opening at a temperature less than a pre-selected temperature.
5581. A system configurable to heat a relatively low permeability foimation containing heavy hydrocarbons, comprising: a heater configurable to be placed in an opening in the formation, wherein the heater is configurable to provide heat to at least a portion of the formation during use; an oxidizing fluid source, wherein an oxidizing fluid is selected to oxidize at least some hydrocarbons at a reaction zone during use such that heat is generated in the reaction zone; a first conduit configurable to be placed in the opening, wherein the first conduit is configurable to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use; and; a second conduit configurable to be placed in the opening, wherein the second conduit is configurable to remove a product of oxidation from the opening during use; and wherein the system is configurable to allow the generated heat to fransfer from the reaction zone to the formation during use.
5582. The system ofclaim 5581, wherein the second conduit is conflgurable to control the concentration of oxygen in the opening during use such that the concenfration of oxygen in the opening is substantially constant in the opening.
5583. The system of claim 5581, wherein the second conduit comprises orifices, and wherein the second conduit comprises a greater concenfration of orifices towards an upper end of the second conduit.
5584. The system ofclaim 5581, wherein the first conduit comprises orifices that direct oxidizing fluid in a direction substantially opposite the second conduit.
5585. The system ofclaim 5581, wherein the second conduit comprises orifices that remove the oxidation product from a direction substantially opposite the first conduit.
5586. The system ofclaim 5581, wherein the second conduit is configurable to remove a product of oxidation from the opening during use such that the reaction zone comprises a substantially uniform temperature profile.
5587. The system ofclaim 5581, wherein a flow of the oxidizing fluid can be varied along a portion of a length of the ffrst conduit,
5588. The system of claim 5581 , wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.
5589. The system ofclaim 5581, wherein the system is configurable to allow heat to transfer from the reaction zone to a pyrolysis zone in the formation during use.
5590. The system ofclaim 5581, wherein the system is configurable to allow heat to fransfer substantially by conduction from the reaction zone to the formation during use.
5591. The system of clahn 5581, wherein a flow of oxidizing fluid can be confrolled along at least a portion of a length of the first conduit such that a temperature can be controlled along at least a portion of the length of the first conduit during use.
5592. The system ofclaim 5581, wherein a flow of oxidizing fluid can be confrolled along at least a portion of the length of the first conduit such that a heating rate in at least a portion of the formation can be confrolled.
5593. The system ofclaim 5581, wherein the oxidizing fluid is configurable to generate heat in the reaction zone during use such that the oxidizing fluid is transported through the reaction zone during use substantially by diffusion, wherein a rate of diffusion can controlled by a temperature of the reaction zone.
5594. The system ofclaim 5581, wherein the first conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening during use.
5595. The system ofclaim 5581, wherein the first conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is confrolled during use.
5596. The system ofclaim 5581, wherein the second conduit is further configurable to remove an oxidation product such that the oxidation product fransfers heat to the oxidizing fluid in the first conduit during use.
5597. The system ofclaim 5581, wherein a pressure of the oxidizing fluid in the first conduit and a pressure of the oxidation product in the second conduit are controlled during use such that a concentration of the oxidizing fluid in along the length of the conduit is substantially uniform.
5598. The system ofclaim 5581, wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone during use.
5599. The system ofclaim 5581, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone during use.
5600. The system ofclaim 5581 , wherein the portion of the formation extends radially from the opening a distance of less than approximately 3 m.
5601. The system ofclaim 5581, wherein the reaction zone extends radially from the opening a distance of less than approximately 3 m.
5602. The system ofclaim 5581, wherein the system is further conflgurable such that fransfened heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.
5603. The system ofclaim 5581, wherein the heater is configured to be placed in an opening in the formation and wherein the heater is configured to provide heat to at least a portion of the formation during use.
5604. The system ofclaim 5581, wherein the first conduit is configured to be placed in the opening, and wherein the first conduit is configured to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use.
5605. The system ofclaim 5581, wherein the flow of oxidizing fluid can be controlled along at least a segment of the ffrst conduit.
5606. The system ofclaim 5581, wherein the second conduit is configured to be placed in the opening, and wherein the second conduit is configured to remove a product of oxidation from the opening during use.
5607. The system ofclaim 5581, wherein the system is configured to allow heat to fransfer from the reaction zone to the foπnation during use.
5608. An in situ method for heating a relatively low permeability formation containing heavy hydrocarbons, comprising: heating a portion of the foπnation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizhig fluid; providing the oxidizing fluid to a reaction zone in the foimation; allowing the oxidizing fluid to react with at least a portion of the hydrocarbons in the reaction zone to generate heat in the reaction zone; removing an oxidation product from the opening; and fransfening the generated heat from the reaction zone to the formation.
5609. The method ofclaim 5608, further comprising removing the oxidation product such that a concenfration of oxygen in the openhig is substantially constant in the opening.
5610. The method ofclaim 5608, further comprising removing the oxidation product from the opening and maintaining a substantially uniform temperature profile within the reaction zone.
5611. The method of claim 5608, further comprising transporting the oxidizing fluid through the reaction zone substantially by diffusion.
5612. The method of claim 5608, further comprising ttansporting the oxidizing fluid through the reaction zone by diffusion, wherein a rate of diffusion is controlled by a temperature of the reaction zone.
5613. The method of claim 5608, further comprising allowing heat to ttansfer from the reaction zone to a pyrolysis zone in the formation.
5614. The method ofclaim 5608, further comprising allowing heat to fransfer from the reaction zone to the formation substantially by conduction.
5615. The method ofclaim 5608, further comprising controlling a flow of the oxidizing fluid along at least a portion of the length of the reaction zone such that a temperature is controlled along at least a portion of the length of the reaction zone.
5616. The method of claim 5608, ftirther comprising confrolling a flow of the oxidizing fluid along at least a portion of the length of the reaction zone such that a heating rate is confrolled along at least a portion of the length of the reaction zone.
5617. The method of claim 5608, further comprising allowing at least a portion of the oxidizing fluid into the opening through orifices of a conduit placed in the openhig.
5618. The method ofclaim 5608, further comprising confrolling a flow of the oxidizing fluid with critical flow orifices in a conduit placed in the opening such that a rate of oxidation is controlled.
5619. The method of claim 5608, further comprising controlling a flow of the oxidizing fluid with a spacing of critical flow orifices in a conduit placed in the opening.
5620. The method ofclaim 5608, further comprising confrolling a flow of the oxidizhig fluid with a diameter of critical flow orifices in a conduit placed in the openhig.
5621. The method ofclaim 5608, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.
5622. The method of claim 5608, wherein a conduit is placed in the opening, and further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.
5623. The method o claim 5608, further comprising removing an oxidation product from the formation through a conduit placed in the opening.
5624. The method ofclaim 5608, further comprising removing an oxidation product from the formation through a conduit placed in the opening and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.
5625. The method ofclaim 5608, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.
5626. The method of claim 5608, further comprising removing water from the formation prior to heating the portion.
5627. The method ofclaim 5608, further comprising providing additional heat to the formation from an electric heater placed in the opening.
5628. The method ofclaim 5608, further comprising providing additional heat to the fonnation from an electric heater placed in the opening such that the oxidizing fluid continuously oxidizes at least a portion of the hydrocarbons in the reaction zone.
5629. The method of clahn 5608, further comprising providing additional heat to the formation from an elecfric heater placed in the opening such that a constant heat rate in the foimation is maintained.
5630. The method ofclaim 5608, further comprising providing additional heat to the formation from an elecfric heater placed in the opening such that the oxidation of at least a portion of the hydrocarbons does not bum out.
5631. The method ofclaim 5608, further comprising generating elecfricity using oxidation products removed from the foπnation.
5632. The method ofclaim 5608, further comprising using oxidation products removed from the formation in an afr compressor.
5633. The method of claim 5608, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volmne of the reaction zone over time.
5634. The method ofclaim 5608, further comprishig increasing the amount of heat provided to the foπnation by increasing the reaction zone.
5635. The method ofclaim 5608, further comprising assessing a temperature in or proximate the opening, and confrolling the flow of oxidizing fluid as a function of the assessed temperature.
5636. The method ofclaim 5608, further comprising assessing a temperature in or proximate the opening, and increasing the flow of oxidizing fluid as the assessed temperature decreases.
5637. The method ofclaim 5608, further comprising controlling the flow of oxidizing fluid to maintain a temperature in or proximate the opening at a temperature less than a pre-selected temperature.
5638. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprishig: providing heat from one or more heat sources to at least one portion of the fonnation; allowing the heat to transfer from the one or more heat sources to a selected section of the formation; controlling the heat from the one or more heat sources such that an average temperature within at least a selected section of the formation is less than about 375 °C; producing a mixture from the formation from a production well; and confrolling heating in or proximate the production well to produce a selected yield of non-condensable hydrocarbons in the produced mixture.
5639. The method ofclaim 5638, further comprising controlling heating in or proximate the production well to produce a selected yield of condensable hydrocarbons in the produced mixture.
5640. The method ofclaim 5638, wherein the mixture comprises more than about 50 weight percent non- condensable hydrocarbons.
5641. The method ofclaim 5638, wherein the mixture comprises more than about 50 weight percent condensable hydrocarbons.
5642. The method ofclaim 5638, wherein the average temperature and a pressure within the formation are controlled such that production of carbon dioxide is substantially inhibited.
5643. The method of claim 5638, heating in or proximate the production well is controlled such that production of carbon dioxide is substantially inhibited.
5644. The method ofclaim 5638, wherein at least a portion of the mixture produced from a first portion of the formation at a lower temperature is recycled into a second portion of the formation at a higher temperature such that production of carbon dioxide is substantially inhibited.
5645. The method ofclaim 5638, wherein the mixture comprises a volume ratio of molecular hydrogen to carbon monoxide of about 2 to 1, and wherein producing the mixture is controlled such that the volume ratio is maintained between about 1.8 to 1 and about 2.2 to 1.
5646. The method ofclaim 5638, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
5647. The method ofclaim 5638, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the foπnation is at least about 0.5 bars absolute.
5648. The method ofclaim 5638, wherein at least one heat source comprises a heater.
5649. A method of freating a relatively low penneability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the foπnation; confrolling the heat from the one or more heat sources such that an average temperature within at least a selected section of the formation is less than about 375 °C; and producing a mixture from the formation.
5650. The method of claim 5649, removing a fluid from the formation through a production well.
5651. The method of claim 5649, further comprising removing a liquid through a production well.
5652. The method of claim 5649, further comprising removing water through a production well.
5653. The method of clahn 5649, further comprising removing a fluid through a production well prior to providing heat to the foimation.
5654. The method ofclaim 5649, fuither comprising removing water from the formation through a production well prior to providing heat to the foimation.
5655. The method ofclaim 5649, further comprising removing the fluid through a production well using a pump.
5656. The method of claim 5649, further comprising removing a fluid through a conduit.
5657. The method of claim 5649, wherein the heat provided from at least one heat source is transfened to the foπnation substantially by conduction.
5658. The method ofclaim 5649, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5659. The method of claim 5649, wherein at least one heat source comprises a heater.
5660. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion of the formation; allowing the heat to transfer from the one or more heat sources to a selected section of the foimation; confrolling the heat from the one or more heat sources such that an average temperature within at least a selected section of the formation is less than about 375 °C; measuring a temperature within a wellbore placed in the foπnation; and producing a mixture from the formation.
5661. The method of claim 5660, further comprising measuring the temperature using a moveable thermocouple.
5662. The method ofclaim 5660, further comprishig measuring the temperature using an optical fiber assembly.
5663. The method ofclaim 5660, further comprising measuring the temperature within a production well.
5664. The method of claim 5660, further comprising measuring the temperature within a heater well.
5665. The method ofclaim 5660, further comprising measuring the temperature within a monitoring well.
5666. The method ofclaim 5660, further comprising providing a pressure wave from a pressure wave source into the wellbore, wherehi the wellbore comprises a plurality of discontinuities along a length of the wellbore, measuring a reflection signal of the pressure wave, and using the reflection signal to assess at least one temperature between at least two discontinuities.
5667. The method of claim 5660, ftuther comprising assessing an average temperature in the formation using one or more temperatures measured within at least one wellbore.
5668. The method ofclaim 5660, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
5669. The method ofclaim 5660, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5670. The method ofclaim 5660, wherein at least one heat source comprises a heater.
5671. An in situ method of measuring assessing a temperature within a wellbore in a relatively low peπneability foπnation containing heavy hydrocarbons, comprising:
providing a pressure wave from a pressure wave source into the wellbore, wherein the wellbore comprises a plurality of discontinuities along a length of the wellbore; measuring a reflection signal of the pressure wave; and using the reflection signal to assess at least one temperature between at least two discontinuities.
5672. The method ofclaim 5671, wherein the plurality of discontinuities are placed along a length of a conduit placed in the wellbore.
5673. The method of claim 5672, wherein the pressure wave is propagated through a wall of the conduit.
5674. The method of claim 5672, wherein the plurality of discontinuities comprises collars placed within the conduit.
5675. The method of claim 5672, wherein the plurality of discontinuities comprises welds placed within the conduit.
5676. The method ofclaim 5671, wherein determining the at least one temperature between at least the two discontinuities comprises relating a velocity of the pressure wave between discontinuities to the at least one temperature.
5677. The method ofclaim 5671, further comprising measuring a reference signal of the pressure wave within the wellbore at an ambient temperature.
5678. The method of clahn 5671, further comprising measuring a reference signal of the pressure wave within the wellbore at an ambient temperature, and then determining the at least one temperature between at least the two discontinuities by comparing the measured signal to the reference signal.
5679. The method of claim 5671 , wherein the at least one temperature is a temperature of a gas between at least the two discontinuities.
5680. The method of claim 5671 , wherein the wellbore comprises a production well.
5681. The method ofclaim 5671, wherein the wellbore comprises a heater well.
5682. The method ofclaim 5671, wherein the wellbore comprises a monitoring well.
5683. The method ofclaim 5671, wherein the pressure wave source comprises a solenoid valve.
5684. The method of claim 5671, wherein the pressure wave source comprises an explosive device.
5685. The method of clahn 5671, wherein the pressure wave source comprises a sound device.
5686. The method of claim 5671, wherein the pressure wave is propagated through the wellbore.
5687. The method ofclaim 5671, wherein the plurality of discontinuities have a spacing between each discontinuity of about 5 m.
5688. The method ofclaim 5671, further comprising repeatedly providing the pressure wave into the wellbore at a selected frequency and continuously measuring the reflected signal to increase a signal-to-noise ratio of the reflected signal.
5689. The method ofclaim 5671, further comprising providing heat from one or more heat sources to a portion of the formation.
5690. The method ofclaim 5671, further comprising pyrolyzing at least some hydrocarbons within a portion of the foπnation.
5691. The method ofclaim 5671, further comprising generating synthesis gas in at least a portion of the foπnation.
5692. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the foπnation; controlling the heat from the one or more heat sources such that an average temperature within at least a majority of the selected section of the formation is less than about 375 °C; and producing a mixture from the foimation through a heater well.
5693. The method ofclaim 5692, wherein producing the mixture through the heater well increases a production rate of the mixture from the formation.
5694. The method ofclaim 5692, further comprising providing heat using at least 2 heat sources.
5695. The method ofclaim 5692, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons with the selected section of the foπnation.
5696. The method ofclaim 5692, wherein the one or more heat sources comprise a pattern of heat sources in a formation, and wherein supeφosition of heat from the pattern of heat sources pyrolyzes at least some hydrocarbons with the selected section of the formation.
5697. The method of claim 5692, wherein heating of a majority of selected section is controlled such that a temperature of the majority of the selected section is less than about 375 °C.
5698. The method of claim 5692, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
5699. The method of clahn 5692, wherein the mixture is produced from the foπnation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5700. The method ofclaim 5692, wherein at least one heat source comprises a heater.
5701. A method of freating a relatively low permeability foπnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; wherein heating is provided from at least a ffrst heat source and at least a second heat source, wherein the first heat source has a first heating cost and the second heat source has a second heating cost; controlling a heating rate of at least a portion of the selected section to preferentially use the first heat source when the first heating cost is less than the second heating cost; and confrolling the heat from the one or more heat sources to pyrolyze at least some hydrocarbon in the selected section of the foimation.
5702. The method of clahn 5701, further comprising confrolling the heating rate such that a temperature within at least a majority of the selected section of the formation is less than about 375 °C.
5703. The method ofclaim 5701, further comprising providing heat using at least 2 heat sources.
5704. The method ofclaim 5701, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons with the selected section of the formation.
5705. The method ofclaim 5701, wherein the one or more heat sources comprise a pattern of heat sources in a fonnation, and wherein supeφosition of heat from the pattern of heat sources pyrolyzes at least some hydrocarbons with the selected section of the foπnation.
5706. The method of clahn 5701, further comprising controlling the heating to preferentiaUy use the second heat source when the second heating cost is less than the first heating cost.
5707. The method ofclaim 5701, further comprising producing a mixture from the formation.
5708. The method ofclaim 5701, wherein heating of a majority of selected section is controlled such that a temperature of the majority of the selected section is less than about 375 °C.
5709. The method ofclaim 5701, wherein the heat provided from at least one heat source is transfened to the formation substantially by conduction.
5710. The method ofclaim 5701, wherein at least one heat source comprises aheater.
5711. The method of claim 5701, further comprising producing a mixture from the formation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5712. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion of the formation; allowing the heat to ttansfer from the one or more heat sources to a selected section of the formation; wherein heating is provided from at least a first heat source and at least a second heat source, wherein the first heat source has a first heathig cost and the second heat source has a second heating cost; controlling a heating rate of at least a portion of the selected section such that a cost associated with heating the selected section is minimized; and controlling the heat from the one or more heat sources to pyrolyze at least some hydrocarbon in at least a portion of the selected section of the formation.
5713. The method ofclaim 5712, wherein the heating rate is varied within a day depending on a cost associated with heating at various times in the day.
5714. The method ofclaim 5712, further comprising confrolling the heating rate such that a temperature within at least a majority of the selected section of the formation is less than about 375 °C.
5715. The method ofclaim 5712, further comprising providing heat using at least 2 heat sources.
5716. The method ofclaim 5712, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons with the selected section of the foimation.
5717. The method of claim 5712, wherein the one or more heat sources comprise a pattern of heat sources in a formation, and wherein supeφosition of heat from the pattern of heat sources pyrolyzes at least some hydrocarbons with the selected section of the formation.
5718. The method of clahn 5712, further comprising producing a mixture from the formation.
5719. The method ofclaim 5712, wherein heating of a majority of selected section is controlled such that a temperature of the majority of the selected section is less than about 375 °C.
5720. The method ofclaim 5712, wherein the heat provided from at least one heat source is transfened to the fonnation substantially by conduction.
5721. The method ofclaim 5712, wherein at least one heat source comprises a heater.
5722. The method ofclaim 5712, further comprising producing a mixture from the formation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5723. A method for controlling an in situ system of treating a relatively low penneability formation containing heavy hydrocarbons, comprising: monitoring at least one acoustic event within the foimation using at least one acoustic detector placed within a wellbore in the formation; recording at least one acoustic event with an acoustic monitoring system; analyzing at least one acoustic event to determine at least one property of the formation; and controlling the in situ system based on the analysis of the at least one acoustic event.
5724. The method of clahn 5723, wherein the at least one acoustic event comprises a seismic event.
5725. The method ofclaim 5723, wherein the method is continuously operated.
5726. The method ofclaim 5723, wherein the acoustic monitoring system comprises a seismic monitoring system.
5727. The method of claim 5723, further comprishig recording the at least one acoustic event with the acoustic monitoring system.
5728. The method ofclaim 5723, further comprising monitoring more than one acoustic event simultaneously with the acoustic monitoring system.
5729. The method of clahn 5723, further comprising monitoring the at least one acoustic event at a sampling rate of about at least once every 0.25 milliseconds.
5730. The method ofclaim 5723, wherein analyzing the at least one acoustic event comprises inteφreting the at least one acoustic event.
5731. The method ofclaim 5723, wherein the at least one property of the formation comprises a location of at least one fracture in the fonnation.
5732. The method ofclaim 5723, wherein the at least one property of the formation comprises an extent of at least one fracture in the formation.
5733. The method ofclaim 5723, wherein the at least one property of the foπnation comprises an orientation of at least one fracture in the formation.
5734. The method ofclaim 5723, wherein the at least one property of the foimation comprises a location and an extent of at least one fracture in the formation.
5735. The method of claim 5723, wherein confrolling the in situ system comprises modifying a temperature of the in situ system.
5736. The method ofclaim 5723, wherein confrolling the in situ system comprises modifying a pressure of the in situ system.
5737. The method of claim 5723, wherein the at least one acoustic detector comprises a geophone.
5738. The method ofclaim 5723, wherein the at least one acoustic detector comprises a hydrophone.
5739. The method ofclaim 5723, further comprising providing heat to at least a portion of the formation.
5740. The method of claim 5723, further comprising pyrolyzing hydrocarbons within at least a portion of the formation.
5741. The method ofclaim 5723, further comprising providing heat from one or more heat sources to a portion of the formation.
5742. The method ofclaim 5723, further comprising pyrolyzing at least some hydrocarbons within a portion of the formation.
5743. The method of clahn 5723, further comprising generating synthesis gas in at least a portion of the formation.
5744. A method of predicting characteristics of a fonnation fluid produced from an in situ process, wherein the in situ process is used for freating a relatively low permeability formation containing heavy hydrocarbons, comprising: determining an isothermal experimental temperature that can be used when treating a sample of the formation, wherein the isothermal experimental temperature is conelated to a selected in situ heating rate for the formation; and treating a sample of the formation at the determined isothermal experimental temperature, wherein the experiment is used to assess at least one product characteristic of the foimation fluid produced from the foimation for the selected heating rate.
5745. The method ofclaim 5744, further comprising determining the at least one product characteristic at a selected pressure.
5746. The method ofclaim 5744, further comprising modifying the selected heating rate so that at least one desfred product characteristic of the formation fluid is obtained.
5747. The method of claim 5744, further comprising using a selected well spacing in the formation to deteπnine the selected heating rate.
5748. The method ofclaim 5744, further comprising using a selected heat input into the formation to determine the selected heating rate.
5749. The method ofclaim 5744, further comprising using at least one property of the formation to deteπnine the selected heating rate.
5750. The method of claim 5744, further comprising selecting a deshed heating rate such that at least one desired product characteristic of the foπnation fluid is obtained.
5751. The method of claim 5744, further comprising determining the isothermal temperature using an equation that estimates a temperature in which a selected amount of hydrocarbons in the formation are converted.
5752. The method ofclaim 5744, wherein the selected heating rate is less than about 1 °C per day.
5753. The method ofclaim 5744, wherein the sample is treated in an insulated vessel.
5754. The method ofclaim 5744, wherein at least one assessed produced characteristic is used to design at least one surface processing system, wherein the surface processing system is used to treat produced fluids on the surface.
5755. The method ofclaim 5744, wherein the formation is treated using a heating rate of about the selected heathig rate.
5756. The method ofclaim 5744, further comprising using at least one product characteristic to assess a pressure to be maintained in the formation during freatment.
5757. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the foπnation; adding hydrogen to the selected section after a temperature of the selected section is at least about 270 °C; and producing a mixture from the formation.
5758. The method ofclaim 5757, wherein the temperature of the selected section is at least about 290 °C.
5759. The method of claim 5757, wherein the temperature of the selected section is at least about 320 °C.
5760. The method ofclaim 5757, wherehi the temperature of the selected section is less than about 375 °C.
5761. The method of claim 5757, wherein the temperature of the selected section is less than about 400 °C.
5762. The method of claim 5757, wherein the heat provided from at least one heat source is transfened to the formation substantially by conduction.
5763. The method of claim 5757, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5764. The method of claim 5757, wherein at least one heat source comprises a heater.
5765. A method of freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion of the formation; allowing the heat to fransfer from the one or more heat sources to a selected section of the formation; and
confrolling a temperature of a majority of the selected section by selectively adding hydrogen to the formation.
5766. The method of clahn 5765, further comprising controlling the temperature such that the temperature is less than about 375 °C.
5767. The method of claim 5765, further comprising controlling the temperature such that the temperature is less than about 400 °C.
5768. The method ofclaim 5765, further comprising controlling a heating rate such that the temperature is less than about 375 °C.
5769. The method ofclaim 5765, wherein the one or more heat sources comprise a pattern of heat sources in a formation, and wherein supeφosition of heat from the pattern of heat sources pyrolyzes at least some hydrocarbons with the selected section of the formation.
5770. The method ofclaim 5765, further comprising producing a mixture from the formation.
5771. The method of claim 5765, wherein the heat provided from at least one heat source is transfened to the formation substantially by conduction.
5772. The method of claim 5765, further comprising producing a mixture from the formation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5773. The method of claim 5765, wherein at least one heat source comprises a heater.
5774. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from at least the portion to a selected section of the formation; and producing fluids from the formation wherein at least a portion of the produced fluids have been heated by the heat provided by one or more of the heat sources, and wherein at least a portion of the produced fluids are produced at a temperature greater than about 200 °C.
5775. The method ofclaim 5774 wherein at least a portion of the produced fluids are produced at a temperature greater than about 250 °C.
5776. The method ofclaim 5774 wherein at least a portion of the produced fluids are produced at a temperature greater than about 300 °C.
5777. The method of clahn 5774, further comprising varying the heat provided to the one or more heat sources to vary heat in at least a portion of the produced fluids.
5778. The method of clahn 5774 wherein the produced fluids are produced from a well comprising at least one of the heat sources, and further comprising varying the heat provided to the one or more heat sources to vary heat in at least a portion of the produced fluids.
5779. The method of claim 5774, further comprising providing at least a portion of the produced fluids to a hydrofreating unit.
5780. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a hydrofreating unit, and further comprising varying the heat provided to the one or more heat sources to vary heat in at least a portion of the produced fluids provided to the hydrofreating unit.
5781. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a hydrofreating unit, and using heat in the produced fluids when hydrotreating at least a portion of the produced fluids.
5782. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, and hydrofreating at least a portion of the produced fluids without using a surface heater to heat produced fluids.
5783. The method of clahn 5774, further comprising: providing at least a portion of the produced fluids to a hydrofreating unit; and hydrotreating at least a portion of the produced fluids; wherein at least 50% of heat used for hydrotreating is provided by heat in the produced fluids.
5784. The method of claim 5774, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, wherein at least a portion of the produced fluids are provided to the hydrotreating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.
5785. The method of claim 5774, further comprising providing at least a portion of the produced fluids to a hydrofreating unit, wherein at least a portion of the produced fluids are provided to the hydrotreating unit via a heated conduit.
5786. The method of claim 5774, further comprishig providing at least a portion of the produced fluids to a hydrotreating unit wherein the produced fluids are produced at a wellhead, and wherein at least a portion of the produced fluids are provided to the hydrotreating unit at a temperature that is within about 50 °C of the temperature of the produced fluids at the wellhead.
5787. The method ofclaim 5774, further comprising hydrofreating at least a portion of the produced fluids such that the volume of hydrofreated produced fluids is about 4% greater than a volume of the produced fluids.
5788. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a hydrofreating unit wherein the produced fluids comprise molecular hydrogen, and using the molecular hydrogen in the produced fluids to hydrotreat at least a portion of the produced fluids.
5789. The method of claim 5774, further comprising providing at least a portion of the produced fluids to a hydrotreating unit wherein the produced fluids comprise molecular hydrogen, hydrotreating at least a portion of the produced fluids, and wherein at least 50% of molecular hydrogen used for hydrofreating is provided by the molecular hydrogen in the produced fluids.
5790. The method of claim 5774 wherein the produced fluids comprise molecular hydrogen, separating at least a portion of the molecular hydrogen from the produced fluids, and providing at least a portion of the separated molecular hydrogen to a surface treatment unit.
5791. The method ofclaim 5774 wherein the produced fluids comprise molecular hydrogen, separating at least a portion of the molecular hydrogen from the produced fluids, and providing at least a portion of the separated molecular hydrogen to an in situ treatment area.
5792. The method of claim 5774 further comprising providing a portion of the produced fluids to an olefin generating unit.
5793. The method of clahn 5774 further comprising providing a portion of the produced fluids to a steam cracking unit.
5794. The method of claim 5774, fuither comprising providing at least a portion of the produced fluids to an olefin generating unit, and further comprising varying heat provided to the one or more heat sources to vary the heat in at least a portion of the produced fluids provided to the olefin generating unit.
5795. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using heat in the produced fluids when generating olefins from at least a portion of the produced fluids.
5796. The method of claim 5774, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and generating olefins from at least a portion of the produced fluids without using a surface heater to heat produced fluids.
5797. The method ofclaim 5774, further comprismg providmg at least a portion of the produced fluids to an olefin generating unit, and generating olefins from at least a portion of the produced fluids, and wherein at least 50% of the heat used for generating olefins is provided by heat in the produced fluids.
5798. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.
5799. The method of claim 5774, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via a heated conduit.
5800. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein the produced fluids are produced at a wellhead, and wherein at least a portion of the produced fluids are provided to the olefin generating unit at a temperature that is within about 50 °C of the temperature of the produced fluids at the wellhead.
5801. The method ofclaim 5774 further comprising removing heat from the produced fluids in a heat exchanger.
5802. The method ofclaim 5774 further comprising separating the produced fluids into two or more streams comprising at least a synthetic condensate sfream, and a non-condensable fluid sfream.
5803. The method of claim 5774 further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids into two or more sfreams.
5804. The method ofclaim 5774 furtlier comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids into two or more streams, and further comprising separating at least one of such sfreams into two or more subsfreams.
5805. The method ofclaim 5774 further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids into three or more sfreams, and wherein such sfreams comprise at least a top stream, a bottom stteam, and a middle stream.
5806. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a separating unit, and further comprising varying heat provided to the one or more heat sources to vary the heat in at least a portion of the produced fluids provided to the separating unit.
5807. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a separating unit, and using heat in the produced fluids when separating at least a portion of the produced fluids.
5808. The method of claim 5774, further comprising providmg at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids without using a surface heater to heat produced fluids.
5809. The method of claim 5774, further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids, and wherein at least 50% of the heat used for separating is provided by heat in the produced fluids.
5810. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a separating unit wherein at least a portion of the produced fluids are provided to the separating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.
5811. The method of claim 5774, further comprising providing at least a portion of the produced fluids to a separating unit wherein at least a portion of the produced fluids are provided to the separating unit via a heated conduit.
5812. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a separating unit wherein the produced fluids are produced at a wellhead, and wherein at least a portion of the produced fluids are provided to the separating unit at a temperature that is within about 50 °C of the temperature of the produced fluids at the wellhead.
5813. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids into four or more sfreams, and wherein such streams comprise at least a top sfream, a bottoms stream, and at least two middle sfreams wherein one of the middle sfreams is heavier than the other middle sfream.
5814. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids into five or more sfreams, and wherein such streams comprise at least a top stream, a bottoms stream, a naphtha sfream, diesel stteam, and a jet fuel sfream.
5815. The method ofclaim 5774, further comprising providing at least a portion of the produced fluids to a distillation column, and using heat in the produced fluids when distilling at least a portion of the produced fluids.
5816. The method of claim 5774 wherein the produced fluids comprise pyrolyzation fluids.
5817. The method of claim 5774 wherein the produced fluids comprise carbon dioxide, and further comprising separating at least a portion of the carbon dioxide from the produced fluids.
5818. The method of claim 5774 wherein the produced fluids comprise carbon dioxide, and further comprising separating at least a portion of the carbon dioxide from the produced fluids, and utilizing at least some carbon dioxide in one or more treatment processes.
5819. The method of claim 5774 wherein the produced fluids comprise molecular hydrogen and wherein the molecular hydrogen is used when treating the produced fluids.
5820. The method ofclaim 5774 wherein the produced fluids comprise steam and wherein the steam is used when treating the produced fluids.
5821. The method of claim 5774, wherein the heat provided from at least one heat source is transfened to the fonnation substantially by conduction.
5822. The method ofclaim 5774, wherein the fluids are produced from the foπnation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5823. The method of claim 5774, wherein at least one heat source comprises a heater.
5824. A method of converting fonnation fluids into olefins, comprising: converting formation fluids into olefins, wherein the foimation fluids are obtained by: providing heat from one or more heat sources to at least a portion of the foπnation; allowing the heat to fransfer from one or more heat sources to a selected section of the formation such that at least some hydrocarbons in the formation are pyrolyzed; and producing fonnation fluids from the foπnation.
5825. The method of claim 5824 wherein the produced fluids comprise steam.
5826. The method ofclaim 5824 wherein the produced fluids comprise steam and wherein the steam in the produced fluids comprises at least a portion of steam used in the olefin generating unit.
5827. The method of claim 5824, further comprising providing at least a portion of the produced fluids to an olefin generating unit.
5828. The method ofclaim 5824, further comprising providing at least a portion of the produced fluids to a steam cracking unit.
5829. The method of claim 5824 wherein olefins comprise ethylene.
5830. The method ofclaim 5824 wherein olefins comprise propylene.
5831. The method ofclaim 5824, further comprising separating liquids from the produced fluids, and then separating olefin generating compounds from the produced fluids, and then providing at least a portion of the olefin generathig compounds to an olefin generating unit.
5832. The method ofclaim 5824 wherein the produced fluids comprise molecular hydrogen, and further comprising removing at least a portion of the molecular hydrogen from the produced fluids prior to using the produced fluids to produce olefins.
5833. The method ofclaim 5824 wherein the produced fluids comprise molecular hydrogen, and further comprising separating at least a portion of the molecular hydrogen from the produced fluids, and utilizing at least a portion of the separated molecular hydrogen in one or more treatment processes.
5834. The method ofclaim 5824 wherein the produced fluids comprise molecular hydrogen, and further comprising removing at least a portion of the molecular hydrogen from the produced fluids using a hydrogen removal unit prior to using the produced fluids to produce olefins.
5835. The method of claim 5824 wherein the produced fluids comprises molecular hydrogen, and further comprising removing at least a portion of the molecular hydrogen from the produced fluids using a membrane prior to using the produced fluids to produce olefins.
5836. The method of claim 5824, further comprising generathig molecular hydrogen during production of olefins, and providing at least a portion of the generated molecular hydrogen to one or more hydrofreating units.
5837. The method of clahn 5824, further comprising generating molecular hydrogen during production of olefins, and providing at least a portion of the generated molecular hydrogen to an in situ treatment area.
5838. The method ofclaim 5824, further comprising generating molecular hydrogen during production of olefins, and providing at least a portion of the generated molecular hydrogen to one or more fuel cells.
5839. The method of claim 5824, further comprising generating molecular hydrogen during production of olefins, and using at least a portion of the generated molecular hydrogen to hydrotteat pyrolysis liquids generated in the olefin generation plant.
5840. The method ofclaim 5824 wherein the produced fluids are at least 200 °C, and further comprising using heat in the produced fluids to produce olefins.
5841. The method ofclaim 5824, further comprising providing at least a portion of the produced fluids to a hydrotreating unit wherein the produced fluids are produced at a wellhead, and wherein at least a portion of the
produced fluids are provided to the olefins generating unit at a temperature that is within about 50 °C of the temperature of the produced fluids at the wellhead.
5842. The method of clahn 5824 wherein the produced fluids can be used to make olefins without substantial hydrofreating of the produced fluids.
5843. The method ofclaim 5824, further comprising separating liquids from the produced fluids, and then using at least a portion of the produced fluids to produce olefins.
5844. The method ofclaim 5824, further comprising controlling a fluid pressure within at least a portion of the formation to enhance production of olefin generating compounds in the produced fluids.
5845. The method ofclaim 5824, further comprising controlling a temperature within at least a portion of the formation to enhance production of olefin generating compounds in the produced fluids.
5846. The method ofclaim 5824, further comprising controlling a temperature profile within at least a portion of the formation to enhance production of olefin generating compounds in the produced fluids.
5847. The method ofclaim 5824, further comprising controlling a heating rate within at least a portion of the formation to enhance production of olefin generating compounds in the produced fluids.
5848. The method ofclaim 5824, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and further comprising varying heat provided to the one or more heat sources to vary the heat in at least a portion of the produced fluids provided to the olefin generating unit.
5849. The method ofclaim 5824, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using heat in the produced fluids when generating olefins from at least a portion of the produced fluids.
5850. The method of claim 5824 wherein the produced fluids comprise steam, and further comprising providing at least a portion of the produced fluids to an olefin generathig unit, and using steam in the produced fluids when generating olefins from at least a portion of the produced fluids.
5851. The method ofclaim 5824 wherein the produced fluids comprise steam, and further comprising providing at least a portion of the produced fluids to an olefin generating unit, generating olefins from at least a portion of the produced fluids, and wherein at least some steam used for generating olefins is provided by the steam in the produced fluids.
5852. The method ofclaim 5824, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.
5853. The method of claim 5824, further comprising providing at least a portion of the produced fluids to an olefm generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via a heated conduit.
5854. The method ofclaim 5824, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise a naphtha fraction, and further comprising providing the naphtha fraction to an olefin generating unit.
5855. The method ofclaim 5824, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise a olefin generating fraction wherein the olefin generating fraction comprises hydrocarbons having a carbon number greater than about 1 and a carbon nmnber less than about 8, and further comprising providing the olefin generating fraction to a olefin generating unit.
5856. The method ofclaim 5824, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise an olefin generating fraction wherein the olefin generating fraction comprises hydrocarbons having a carbon number greater than about 1 and a carbon number less than about 6, and further comprising providing the olefin generating fraction to a olefin generating unit.
5857. The method of clahn 5824, further comprising providing at least the portion of the produced fluids to a component removal unit such that at least one component stream and a reduced component fluid stream are formed, and then providing the reduced component fluid stream to an olefin generating unit.
5858. The method of clahn 5857, wherein the component comprises a metal.
5859. The method of claim 5857, wherein the component comprises arsenic.
5860. The method ofclaim 5857, wherein the component comprises mercury.
5861. The method of claim 5857, wherein the component comprises lead.
5862. The method ofclaim 5824, further comprising providing at least the portion of the produced fluids to a component removal unit such that at least one component stteam and a reduced component fluid stteam are formed, then providing the reduced component fluid sfream to a molecular hydrogen separating unit such that a molecular hydrogen sfream and a reduced hydrogen fluid sfream are formed, then providing the molecular hydrogen sfream to a hydrotreating unit, and then providing the reduced hydrogen produced fluid stream to an olefin generating unit.
5863. The method of clahn 5824 wherein the produced fluids comprise molecular hydrogen and wherein the molecular hydrogen is used when freating the produced fluids.
5864. The method ofclaim 5824 wherein the produced fluids comprise steam and wherein the steam is used when freating the produced fluids.
5865. The method ofclaim 5824, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using heat in the produced fluids when generating olefins from at least a portion of the produced fluids.
5866. The method ofclaim 5824 wherein the produced fluids comprise steam, and further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using steam in the produced fluids when generating olefins from at least a portion of the produced fluids.
5867. The method ofclaim 5824, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.
5868. The method ofclaim 5824, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via a heated conduit.
5869. The method ofclaim 5824, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
5870. The method ofclaim 5824, wherein the formation fluids are produced from the formation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5871. The method ofclaim 5824, wherein at least one heat source comprises aheater.
5872. A method of separating olefins from fluids produced from a relatively low permeability formation containing heavy hydrocarbons, comprising: separating olefins from the produced fluids, wherein the produced fluids are obtained by: providing heat from one or more heat sources to at least a portion of the foπnation; allowing the heat to transfer from at least one or more heat sources to a selected section of the fonnation; and producing fluids from the formation wherein the produced fluids comprise olefins.
5873. The method ofclaim 5872 wherein olefins comprise ethylene.
5874. The method ofclaim 5872 wherein olefins comprise propylene.
5875. The method ofclaim 5872, further comprising separating liquids from the produced fluids.
5876. The method ofclaim 5872 wherein the produced fluids comprise molecular hydrogen, and further comprising separating at least a portion of the molecular hydrogen from the produced fluids, and utilizing at least a portion of the separated molecular hydrogen in one or more freatment processes.
5877. The method ofclaim 5872 wherein the produced fluids comprise molecular hydrogen, and further comprising removing at least a portion of the molecular hydrogen from the produced fluids using a hydrogen removal unit.
5878. The method ofclaim 5872 wherein the produced fluids comprises molecular hydrogen, and further comprising removing at least a portion of the molecular hydrogen from the produced fluids using a membrane.
5879. The method of claim 5872, further comprising confrolling a fluid pressure within at least a portion of the formation to enhance production of olefins in the produced fluids.
5880. The method ofclaim 5872, further comprising controlling a temperature within at least a portion of the formation to enhance production of olefins in the produced fluids.
5881. The method of claim 5872, fuither comprising confrolling a temperature profile within at least a portion of the formation to enhance production of olefins in the produced fluids.
5882. The method ofclaim 5872, ftirther comprising confrolling a heating rate within at least a portion of the formation to enhance production of olefins in the produced fluids.
5883. The method ofclaim 5872, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and further comprising varying heat provided to the one or more heat sources to vary the heat in at least a portion of the produced fluids provided to the olefin generating unit.
5884. The method ofclaim 5872, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using heat in the produced fluids when generating olefins from at least a portion of the produced fluids.
5885. The method of claim 5872 wherein the produced fluids comprise steam, and further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using steam in the produced fluids when generating olefins from at least a portion of the produced fluids.
5886. The method of claim 5872, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.
5887. The method ofclaim 5872, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via a heated conduit.
5888. The method ofclaim 5872, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise a naphtha fraction, and further comprising providing the naphtha fraction to an olefin generating unit.
5889. The method of claim 5872, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise a olefin generating fraction wherein the olefin generating fraction comprises hydrocarbons having a carbon number greater than about 1 and a carbon number less than about 8, and further comprising providing the olefin generathig fraction to a olefin generating unit.
5890. The method ofclaim 5872, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise an olefin generating fraction wherein the olefhi generating fraction comprises hydrocarbons having a carbon number greater than about 1 and a carbon number less than about 6, and further comprising providing the olefin generating fraction to a olefin generating unit.
5891. The method ofclaim 5872, further comprising providing at least the portion of the produced fluids to a component removal unit such that at least one component stream and a reduced component fluid sfream are formed, and then providing the reduced component fluid stteam to an olefin generating unit.
5892. The method of claim 5891 wherein the component comprises a metal.
5893. The method ofclaim 5891 wherein the component comprises arsenic.
5894. The method ofclaim 5891 wherein the component comprises mercury.
5895. The method ofclaim 5891 wherein the component comprises lead.
5896. The method of clahn 5872, further comprising providing at least the portion of the produced fluids to a component removal unit such that at least one component stream and a reduced component fluid stream are formed, then providing the reduced component fluid stream to a molecular hydrogen separating unit such that a molecular hydrogen sfream and a reduced hydrogen fluid sfream are formed, then providing the molecular hydrogen sfream to a hydrofreating unit, and then providing the reduced hydrogen produced fluid stteam to an olefin generating unit.
5897. The method ofclaim 5872, further comprising confrolling a temperature gradient within at least a portion of the fonnation to enhance production of olefins in the produced fluids.
5898. The method ofclaim 5872, further comprising confrolling a fluid pressure within at least a portion of the formation to enhance production of olefins in the produced fluids.
5899. The method ofclaim 5872, further comprising controlling a temperature within at least a portion of the formation to enhance production of olefins in the produced fluids.
5900. The method of claim 5872, further comprising controlling a heating rate within at least a portion of the formation to enhance production of olefins in the produced fluids.
5901. The method of claim 5872, further comprising separating the olefins from the produced fluids such that an amount of molecular hydrogen utilized in one or more downstream hydrofreating units decreases.
5902. The method of claim 5872, further comprising removing at least a portion of the olefins prior to hydrofreating produced fluids.
5903. A method of enhancing BTEX compounds production from a relatively low peπneability formation containing heavy hydrocarbons, comprising: confrollmg at least one condition within at least a portion of the formation to enhance production of BTEX compounds in formation fluid, wherein the formation fluid is obtained by: providing heat from one or more heat sources to at least a portion of the formation; allowing the heat to fransfer from at least one or more heat sources to a selected section of the fonnation; and producing formation fluids from the formation.
5904. The method ofclaim 5903, further comprising separating at least a portion of the BTEX compounds from the produced fluids.
5905. The method ofclaim 5903, further comprising separating at least a portion of the BTEX compounds from the produced fluids via solvent extraction.
5906. The method of clahn 5903, further comprising separating at least a portion of the BTEX compounds from the produced fluids via distillation.
5907. The method ofclaim 5903, further comprising separating at least a portion of the BTEX compounds from the produced fluids via condensation.
5908. The method ofclaim 5903, further comprising separating at least a portion of the BTEX compounds from the produced fluids such that an amount of molecular hydrogen utilized in one or more downstream hydrotreating units decreases.
5909. The method of claim 5903, wherein controlling at least one condition in the formation comprises controlling a fluid pressure within at least a portion of the foπnation.
5910. The method of claim 5903, wherein controlling at least one condition in the formation comprises controlling a temperature gradient withhi at least a portion of the formation.
5911. The method ofclaim 5903, wherein controlling at least one condition in the formation comprises controlling a temperature within at least a portion of the formation.
5912. The method ofclaim 5903, wherein controlling at least one condition in the formation comprises confrolling a heating rate within at least a portion of the formation.
5913. The method of clahn 5903, further comprising removing at least a portion of the BTEX compounds prior to hydrofreating produced fluids.
5914. The method ofclaim 5903, wherein the heat provided from at least one heat source is fransfened to the foπnation substantially by conduction.
5915. The method of claim 5903, wherein the fonnation fluids are produced from the formation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5916. The method ofclaim 5903, wherein at least one heat source comprises a heater.
5917. A method of separating BTEX compounds from foimation fluid from a relatively low peπneability fonnation containing heavy hydrocarbons, comprising: separating at least a portion of the BTEX compounds from the formation fluid wherein the formation fluid is obtained by: providing heat from one or more heat sources to at least a portion of the foimation;
allowing the heat to fransfer from at least one or more heat sources to a selected section ofthe formation; and producing fluids from the foπnation wherein the produced fluids comprise BTEX compounds.
5918. The method of clahn 5917, further comprising hydrotreating at least a portion ofthe produced fluids after the BTEX compounds have been separated from same.
5919. The method of claim 5917 wherein separating at least a portion of the BTEX compounds from the produced fluids comprises extracting at least the portion ofthe BTEX compounds from the produced fluids via solvent exfraction.
5920. The method ofclaim 5917 wherein separating at least a portion ofthe BTEX compounds from the produced fluids comprises distilling at least the portion ofthe BTEX compounds from the produced fluids.
5921. The method of claim 5917 wherein separating at least a portion of the BTEX compounds from the produced fluids comprises condensing at least the portion ofthe BTEX compounds from the produced fluids
5922. The method ofclaim 5917 wherein separating at least a portion ofthe BTEX compounds from the produced fluids such that an amount of molecular hydrogen utilized in one or more downstream hydrotreating units decreases.
5923. The method ofclaim 5917, further comprising controlling a fluid pressure within at least a portion ofthe formation.
5924. The method of claim 5917, further comprising confrolling a temperature gradient within at least a portion ofthe foπnation.
5925. The method ofclaim 5917, fuither comprising controlling a temperature within at least a portion ofthe formation.
5926. The method ofclaim 5917, further comprising controlling a heating rate within at least a portion ofthe formation.
5927. The method ofclaim 5917 wherein separating at least the portion of BTEX compounds from the produced fluids further comprises removing a naphtha fraction from the produced fluids, and separating at least the portion of
BTEX compounds from the naphtha fraction.
5928. The method of clahn 5917, wherein separating at least the portion of BTEX compounds from the produced fluids, further comprises removing a BTEX fraction from the produced fluids, and separating at some BTEX compounds from the BTEX fraction.
5929. The method ofclaim 5917, wherein separating at least the portion of BTEX compounds from the produced fluids decreases an amount of molecular hydrogen utilized in one or more downstream hydrotreating units.
5930. A method of in situ converting at least a portion of formation fluid into BTEX compounds, comprising: in situ converting at least the portion ofthe foπnation fluid into BTEX compounds, wherein the formation fluid are obtained by: providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to fransfer from at least one or more heat sources to a selected section ofthe formation such that at least some hydrocarbons in the formation are pyrolyzed; and producing formation fluid from the formation.
5931. The method of claim 5930, further comprising providing at least a portion ofthe formation fluid to an BTEX generating unit.
5932. The method of claim 5930, further comprising providing at least a portion ofthe formation fluid to a catalytic reforming unit.
5933. The method of claim 5930, further comprising hydrotreating at least some ofthe formation fluid, and then separating the hydrofreated mixture into one more sfreams comprising a naphtha sfream, and then reforming at least a portion the naphtha stream to form a reformate comprishig BTEX compounds, and then separating at least a portion ofthe BTEX compounds from the reformate.
5934. The method of clahn 5930, further comprising hydrofreating at least some ofthe formation fluid, and then separating the hydrofreated mixture into one more sfreams comprising a naphtha stream, and then reforming at least a portion the naphtha sfream to form a molecular hydrogen stream and a reformate comprising BTEX compounds, and then separating at least a portion of the BTEX compounds from the reformate, and then utilizing the molecular hydrogen stream to hydrotreat at least some ofthe formation fluid.
5935. The method ofclaim 5930, further comprising hydrofreating the foπnation fluid, and then separating the hydrofreated formation fluid into one more sfreams comprising a naphtha stream, and then reforming at least a portion the naphtha sfream to form a reformate comprising BTEX compounds, and then separating at least a portion ofthe refoπnate into two or more streams comprising a raffinate and a BTEX stream..
5936. The method ofclaim 5930 wherein the formation fluid is at least 200 °C, and further comprising using heat in the formation fluid to hydrofreat at least a portion ofthe formation fluid.
5937. The method of claim 5930, further comprising separating at least a portion ofthe formation fluid into one or more fractions wherehi the one or more fractions comprise a naphtha fraction, and further comprising providing the naphtha fraction to a catalytic reforming unit.
5938. The method of clahn 5930, further comprising separating at least a portion ofthe foπnation fluid into one or more fractions wherein the one or more fractions comprise a BTEX compound generating fraction wherein the BTEX compound generating fraction comprises hydrocarbons, and further comprising providing the BTEX compound generating fraction to a catalytic reforming unit.
5939. The method of claim 5930, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
5940. The method of claim 5930, wherein the fluids are produced from the foπnation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5941. The method ofclaim 5930, wherein at least one heat source comprises a heater.
5942. A method of enhancing naphthalene production from a relatively low permeability formation containing heavy hydrocarbons, comprising: confrolling at least one condition within at least a portion ofthe formation to enhance production of naphthalene in formation fluid, wherein the formation fluid is obtained by: providing heat from one or more heat sources to at least a portion ofthe foπnation; allowing the heat to fransfer from at least one or more heat sources to a selected section ofthe foπnation; and producing formation fluids from the foimation.
5943. The method of clahn 5942, further comprising separating at least a portion ofthe naphthalene from the produced fluids.
5944. The method of claim 5942 wherein controlling at least one condition in the formation comprises confrolling a fluid pressure within at least a portion ofthe formation.
5945. The method ofclaim 5942 wherein controlling at least one condition in the foπnation comprises controlling a temperature gradient within at least a portion ofthe formation.
5946. The method of clahn 5942 wherein confrolling at least one condition in the formation comprises confrolling a temperature within at least a portion ofthe formation.
5947. The method ofclaim 5942 wherein controlling at least one condition in the formation comprises controlling a heating rate within at least a portion ofthe formation.
5948. The method ofclaim 5942, further comprising separating the produced fluids into one or more fractions using distillation.
5949. The method ofclaim 5942, further comprising separating the produced fluids into one or more fractions using condensation.
5950. The method ofclaim 5942, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and further comprising providing the heart cut to an exfraction unit, and separating at least some naphthalene from the heart cut.
5951. The method of claim 5942, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a naphthalene fraction, and further comprising providing the naphthalene fraction to an exfraction unit, and separating at least some naphthalene from the naphthalene fraction.
5952. The method ofclaim 5942, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
5953. The method of claim 5942, wherein the foimation fluids are produced from the formation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5954. The method ofclaim 5942, wherein at least one heat source comprises a heater.
5955. A method of separating naphthalene from fluids produced from a relatively low permeability fonnation containing heavy hydrocarbons, comprising: separating naphthalene from the produced fluids, wherein the produced fluids are obtained by: providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from at least one or more heat sources to a selected section ofthe formation; and producing fluids from the formation wherein the produced fluids comprise naphthalene.
5956. The method ofclaim 5955, further comprising controlling a fluid pressure within at least a portion ofthe foπnation.
5957. The method of claim 5955, further comprising controlling a temperature gradient within at least a portion ofthe formation.
5958. The method of claim 5955, further comprising controlling a temperature within at least a portion ofthe formation.
5959. The method ofclaim 5955, further comprising controlling a heating rate within at least a portion ofthe formation.
5960. The method ofclaim 5955, wherein separating at least some naphthalene from the produced fluids further comprises separating the produced fluids into one or more fractions using distillation.
5961. The method ofclaim 5955, wherein separating at least some naphthalene from the produced fluids further comprises separating the produced fluids into one or more fractions using condensation.
5962. The method ofclaim 5955, wherein separating at least some naphthalene from the produced fluids further comprises separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and extracting at least a portion ofthe naphthalene from the heart cut.
5963. The method of claim 5955, wherein separating at least some naphthalene from the produced fluids further comprises removing a naphtha fraction from the produced fluids, and separating at least a portion ofthe naphthalene from the naphtha fraction.
5964. The method ofclaim 5955, wherein separating at least some naphthalene from the produced fluids further comprises removing an naphthalene fraction from the produced fluids, and separating at least a portion ofthe naphthalene from the naphthalene fraction.
5965. The method ofclaim 5955, wherein separating the naphthalene from the produced fluids further comprises removing naphthalene using distillation.
5966. The method of claim 5955, wherein separating the naphthalene from the produced fluids further comprises removing naphthalene using crystallization.
5967. The method of claim 5955, further comprising removing at least a portion ofthe naphthalene prior to hydrotreating produced fluids.
5968. The method ofclaim 5955, wherein the heat provided from at least one heat source is transfened to the formation substantially by conduction.
5969. The method of claim 5955, wherein the foimation fluids are produced from the formation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5970. The method of claim 5955, wherein at least one heat source comprises a heater.
5971. A method of enhancing anthracene production from a relatively low permeability fonnation containing heavy hydrocarbons, comprising: controlling at least one condition within at least a portion ofthe formation to enhance production of anthracene in fonnation fluid, wherein the fonnation fluid is obtained by: providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to fransfer from at least one or more heat sources to a selected section ofthe foπnation; and producing formation fluids from the formation.
5972. The method ofclaim 5971, further comprising separating at least a portion ofthe anthracene from the produced fluids.
5973. The method ofclaim 5971 wherehi confrolling at least one condition in the fonnation comprises confrolling a fluid pressure within at least a portion ofthe foimation.
5974. The method ofclaim 5971 wherein controlling at least one condition in the formation comprises confrolling a temperature gradient within at least a portion ofthe formation.
5975. The method ofclaim 5971 wherein controlling at least one condition in the formation comprises confrolling a temperature withhi at least a portion ofthe formation.
5976. The method ofclaim 5971 wherein confrolling at least one condition in the formation comprises confrolling a heating rate within at least a portion ofthe formation.
5977. The method ofclaim 5971, further comprising separating the produced fluids into one or more fractions using distillation.
5978. The method ofclaim 5971, further comprising separating the produced fluids into one or more fractions using condensation.
5979. The method o claim 5971, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and further comprising providing the heart cut to an extraction unit, and separating at least some anthracene from the heart cut.
5980. The method ofclaim 5971 , further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a anthracene fraction, and further comprising providing the anthracene fraction to an extraction unit, and separating at least some anthracene from the anthracene fraction.
5981. The method ofclaim 5971, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
5982. The method ofclaim 5971, wherein the formation fluids are produced from the formation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5983. The method ofclaim 5971, wherein at least one heat source comprises a heater.
5984. A method of separating anthracene from fluids produced from a relatively low permeability formation containing heavy hydrocarbons, comprising: separating anthracene from the produced fluids, wherein the produced fluids are obtained by: providing heat from one or more heat sources to at least a portion ofthe foπnation; allowing the heat to transfer from at least one or more heat sources to a selected section ofthe formation; and producing fluids from the foimation wherein the produced fluids comprise anthracene.
5985. The method ofclaim 5984, further comprising confrolling a fluid pressure within at least a portion ofthe foπnation.
5986. The method ofclaim 5984, further comprising confrolling a temperature gradient within at least a portion ofthe formation.
5987. The method of clahn 5984, further comprising confrolling a temperature within at least a portion ofthe formation.
5988. The method ofclaim 5984, further comprising controlling a heating rate within at least a portion ofthe formation
5989. The method of claim 5984, wherein separating at least some anthracene from the produced fluids fiuther comprises separating the produced fluids into one or more fractions using distillation.
5990. The method ofclaim 5984, wherein separating at least some anthracene from the produced fluids further comprises separating the produced fluids into one or more fractions using condensation.
5991. The method of claim 5984, wherein separating at least some anthracene from the produced fluids further comprises separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and extracting at least a portion ofthe anthracene from the heart cut.
5992. The method ofclaim 5984, wherein separating at least some anthracene from the produced fluids fiuther comprises removing a naphtha fraction from the produced fluids, and separathig at least a portion ofthe anthracene from the naphtha fraction.
5993. The method of clahn 5984, wherein separating at least some anthracene from the produced fluids further comprises removing an anthracene fraction from the produced fluids, and separating at least a portion ofthe anthracene from the anthracene fraction.
5994. The method of claim 5984, wherein separating the anthracene from the produced fluids further comprises removing anthracene using distillation.
5995. The method of claim 5984, wherein separating the anthracene from the produced fluids further comprises removing anthracene using crystallization.
5996. The method ofclaim 5984, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
5997. The method ofclaim 5984, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
5998. The method of claim 5984, wherein at least one heat source comprises a heater.
5999. A method of separating ammonia from fluids produced from a relatively low permeability formation containing heavy hydrocarbons, comprising: separating at least a portion ofthe ammonia from the produced fluid, wherein the produced fluids are obtained by: providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from at least one or more heat sources to a selected section ofthe formation; and producing fluids from the foπnation.
6000. The method ofclaim 5999 wherein the produced fluids are pyrolyzation fluids.
6001. The method ofclaim 5999 wherein separating at least a portion ofthe ammonia from the produced fluids further comprises providing at least a portion ofthe produced fluids to a sour water stripper.
6002. The method of claim 5999 wherein separating at least a portion ofthe ammonia from the produced fluids further comprises separating the produced fluids into one or more fractions, and providing at least a portion ofthe one or more fractions to a stripping unit.
6003. The method of clahn 5999, further comprising using at least a portion ofthe separated ammonia to generate ammonium sulfate.
6004. The method ofclaim 5999, further comprising using at least a portion ofthe separated ammonia to generate urea.
6005. The method ofclaim 5999 wherein the produced fluids comprise carbon dioxide, and further comprising separating the carbon dioxide from the produced fluids, and reacting the carbon dioxide with at least some ammonia to form urea.
6006. The method ofclaim 5999 wherein the produced fluids comprise hydrogen sulfide, and ftirther comprising separating the hydrogen sulfide from the produced fluids, converting at least some hydrogen sulfide into sulfuric acid, and reacting at lest some sulfuric acid with at lease some ammonia to form ammonium sulfate.
6007. The method of claim 5999 wherein the produced fluids further comprise hydrogen sulfide, and further comprising separating at least a portion ofthe hydrogen sulfide from the produced fluids, and converting at least some hydrogen sulfide into sulfuric acid.
6008. The method of claim 5999, further comprising generating ammonium bicarbonate using separated ammonia.
6009. The method of claim 5999, further comprising providing separated ammonia to a fluid comprising carbon dioxide to generate ammonium bicarbonate.
6010. The method of claim 5999, further comprising providing separated ammonia to at least some synthesis gas to generate ammonium bicarbonate.
6011. The method of clahn 5999, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
6012. The method ofclaim 5999, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the foimation is at least about 0.5 bars absolute.
6013. The method of claim 5999, wherein at least one heat source comprises a heater.
6014. A method of generating ammonia from fluids produced from a relatively low permeability formation containing heavy hydrocarbons, comprising:
hydrofreating at least a portion ofthe produced fluids to generate ammonia wherein the produced fluids are obtained by: providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to fransfer from at least one or more heat sources to a selected section ofthe formation; and producing fluids from the fonnation.
6015. The method of claim 6014 wherein the produced fluids are pyrolyzation fluids.
6016. The method ofclaim 6014, ftuther comprising separating at least a portion ofthe ammonia from the hydrofreated fluids.
6017. The method ofclaim 6014, further comprising using at least a portion ofthe ammonia to generate ammonium sulfate.
6018. The method of claim 6014, further comprising using at least a portion of the ammonia to generate urea.
6019. The method ofclaim 6014 wherein the produced fluids further comprise carbon dioxide, and further comprising separating at least a portion ofthe carbon dioxide from the produced fluids, and reacting at least the portion ofthe carbon dioxide with at least a portion of ammonia to form urea.
6020. The method of claim 6014 wherein the produced fluids further comprise hydrogen sulfide, and further comprishig separating at least a portion ofthe hydrogen sulfide from the produced fluids, converting at least some hydrogen sulfide into sulfuric acid, and reacting at least some sulfuric acid with at least a portion ofthe aimnonia to form ammonium sulfate.
6021. The method ofclaim 6014 wherein the produced fluids further comprise hydrogen sulfide, and further comprising separating at least a portion ofthe hydrogen sulfide from the produced fluids, and converting at least some hydrogen sulfide into sulfuric acid.
6022. The method of claim 6014, further comprising generating ammonium bicarbonate using at least a portion ofthe ammonia.
6023. The method ofclaim 6014, further comprising providing at least a portion ofthe ammonia to a fluid comprishig carbon dioxide to generate ammonium bicarbonate.
6024. The method of claim 6014, further comprising providing at least a portion ofthe ammonia to at least some synthesis gas to generate ammonium bicarbonate
6025. The method ofclaim 6014, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
6026. The method ofclaim 6014, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6027. The method of claim 6014, wherein at least one heat source comprises a heater.
6028. A method of enhancing pyridines production from a relatively low penneability foπnation containing heavy hydrocarbons, comprising: controlling at least one condition within at least a portion ofthe formation to enhance production of pyridines in formation fluid, wherein the formation fluid is obtained by: providing heat from one or more heat sources to at least a portion ofthe fonnation; allowing the heat to fransfer from at least one or more heat sources to a selected section ofthe foπnation; and producing foπnation fluids from the foπnation.
6029. The method of claim 6028, further comprising separating at least a portion ofthe pyridines from the produced fluids.
6030. The method of claim 6028 wherein controlling at least one condition in the formation comprises confrolling a fluid pressure within at least a portion ofthe formation.
6031. The method ofclaim 6028 wherein confrolling at least one condition in the formation comprises confrolling a temperature gradient within at least a portion of the formation.
6032. The method of claim 6028 wherein controlling at least one condition in the formation comprises confrolling a temperature within at least a portion ofthe formation.
6033. The method of claim 6028 wherein controlling at least one condition in the fonnation comprises controlling a heating rate within at least a portion ofthe foimation.
6034. The method ofclaim 6028, further comprising separating the produced fluids into one or more fractions using distillation.
6035. The method ofclaim 6028, further comprising separating the produced fluids into one or more fractions using condensation.
6036. The method of clahn 6028, further comprising separathig the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and further comprising providmg the heart cut to an extraction unit, and separating at least some pyridines from the heart cut.
6037. The method of clahn 6028, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a pyridines fraction, and further comprising providing the pyridines fraction to an extraction unit, and separating at least some pyridines from the pyridines fraction.
6038. The method ofclaim 6028, wherein the heat provided from at least one heat source is transfened to the formation substantially by conduction.
6039. The method ofclaim 6028, wherein the foπnation fluids are produced from the formation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6040. The method ofclaim 6028, wherehi at least one heat source comprises a heater.
6041. A method of separating pyridines from fluids produced from a relatively low permeability foπnation containing heavy hydrocarbons, comprising: separating pyridines from the produced fluids, wherein the produced fluids are obtained by: providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to fransfer from at least one or more heat sources to a selected section ofthe formation; and producing fluids from the formation wherein the produced fluids comprise pyridines.
6042. The method of clahn 6041, further comprising controlling a fluid pressure within at least a portion ofthe formation.
6043. The method of claim 6041 , further comprising controlling a temperature gradient within at least a portion ofthe fonnation.
6044. The method ofclaim 6041, further comprising controlling a temperature within at least a portion ofthe formation.
6045. The method of claim 6041 , further comprising confrolling a heating rate within at least a portion of the formation
6046. The method ofclaim 6041 wherein separating at least some pyridines from the produced fluids further comprises separating the produced fluids into one or more fractions using distillation.
6047. The method of clahn 6041 wherein separating at least some pyridines from the produced fluids fiuther comprises separating the produced fluids into one or more fractions using condensation.
6048. The method of clahn 6041 wherein separating at least some pyridines from the produced fluids further comprises separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and extracting at least a portion ofthe pyridines from the heart cut.
6049. The method ofclaim 6041 wherein separating at least some pyridines from the produced fluids further comprises removing a naphtha fraction from the produced fluids, and separating at least a portion ofthe pyridines from the naphtha fraction.
6050. The method ofclaim 6041, wherein separathig at least some pyridines from the produced fluids further comprises removing an pyridines fraction from the produced fluids, and separating at least a portion ofthe pyridines from the pyridines fraction.
6051. The method ofclaim 6041, wherein separating the pyridines from the produced fluids further comprises removing pyridines using distillation.
6052. The method of claim 6041 , wherein separating the pyridines from the produced fluids further comprises removing pyridines using crystallization.
6053. The method ofclaim 6041, wherein the heat provided from at least one heat source is transfened to the formation substantially by conduction.
6054. The method ofclaim 6041, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6055. The method of claim 6041 , wherein at least one heat source comprises a heater.
6056. A method of enhancing pynoles production from a relatively low permeability formation containing heavy hydrocarbons, comprising: confrolling at least one condition within at least a portion ofthe formation to enhance production of pynoles in formation fluid, wherein the formation fluid is obtained by: providing heat from one or more heat sources to at least a portion ofthe fonnation; allowing the heat to transfer from at least one or more heat sources to a selected section ofthe foπnation; and producing foπnation fluids from the foπnation.
6057. The method ofclaim 6056, further comprising separating at least a portion ofthe py oles from the produced fluids.
6058. The method of clahn 6056 wherein controlling at least one condition in the formation comprises controlling a fluid pressure within at least a portion of the foimation.
6059. The method of claim 6056 wherein confrolling at least one condition in the formation comprises controlling a temperature gradient within at least a portion ofthe foimation.
6060. The method of claim 6056 wherein controlling at least one condition in the fonnation comprises controlling a temperature withhi at least a portion ofthe formation.
6061. The method of claim 6056 wherein controlling at least one condition in the formation comprises confroUhig a heating rate within at least a portion ofthe foimation.
6062. The method of claim 6056, further comprising separating the produced fluids into one or more fractions using distillation.
6063. The method ofclaim 6056, further comprising separating the produced fluids into one or more fractions using condensation.
6064. The method of clahn 6056, further comprismg separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and further comprising providing the heart cut to an extraction unit, and separating at least some pynoles from the heart cut.
6065. The method ofclaim 6056, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a pynoles fraction, and further comprising providing the pynoles fraction to an exfraction unit, and separating at least some pynoles from the pynoles fraction.
6066. The method of claim 6056, wherein the heat provided from at least one heat source is transfened to the formation substantially by conduction.
6067. The method of claim 6056, wherein the formation fluids are produced from the formation when a partial pressure ofhydrogen in at least a portion the foimation is at least about 0.5 bars absolute.
6068. The method ofclaim 6056, wherein at least one heat source comprises a heater.
6069. A method of separating pynoles from fluids produced from a relatively low permeability foπnation containing heavy hydrocarbons, comprising:
separating pynoles from the produced fluids, wherein the produced fluids are obtained by: providing heat from one or more heat sources to at least a portion ofthe foπnation; allowing the heat to transfer from at least one or more heat sources to a selected section ofthe formation; and producing fluids from the foπnation wherein the produced fluids comprise pynoles.
6070. The method ofclaim 6069, further comprising confrolling a fluid pressure within at least a portion ofthe formation.
6071. The method of claim 6069, further comprismg controlling a temperature gradient within at least a portion ofthe formation.
6072. The method ofclaim 6069, further comprising confrolling a temperature within at least a portion ofthe formation.
6073. The method of claim 6069, further comprising controlling a heating rate within at least a portion ofthe formation
6074. The method ofclaim 6069, wherein separating at least some pynoles from the produced fluids further comprises separating the produced fluids into one or more fractions using distillation.
6075. The method of claim 6069, wherein separating at least some pynoles from the produced fluids further comprises separating the produced fluids into one or more fractions using condensation.
6076. The method of clahn 6069, wherehi separating at least some pynoles from the produced fluids further comprises separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and extracting at least a portion ofthe pynoles from the heart cut.
6077. The method ofclaim 6069, wherein separating at least some pynoles from the produced fluids ftirther comprises removing a naphtha fraction from the produced fluids, and separating at least a portion ofthe pynoles from the naphtha fraction.
6078. The method ofclaim 6069, wherein separating at least some pynoles from the produced fluids further comprises removing an pynoles fraction from the produced fluids, and separating at least a portion ofthe pynoles from the pynoles fraction.
6079. The method of claim 6069, wherein separating the pynoles from the produced fluids further comprises removing pynoles using distillation.
6080. The method of claim 6069, wherein separating the pynoles from the produced fluids further comprises removing pynoles using crystallization.
6081. The method of claim 6069, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
6082. The method of claim 6069, wherein the fluids are produced from the foimation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6083. The method of claim 6069, wherein at least one heat source comprises a heater.
6084. A method of enhancing thiophenes production from a relatively low permeability formation containing heavy hydrocarbons, comprising: confrolling at least one condition within at least a portion ofthe foπnation to enhance production of thiophenes in formation fluid, wherein the formation fluid is obtained by: providing heat from one or more heat sources to at least a portion ofthe fonnation; allowing the heat to fransfer from at least one or more heat sources to a selected section ofthe formation; and producing formation fluids from the fonnation.
6085. The method ofclaim 6084, further comprising separating at least a portion ofthe thiophenes from the produced fluids.
6086. The method of claim 6084, wherein controlling at least one condition in the foπnation comprises controlling a fluid pressure within at least a portion ofthe formation.
6087. The method ofclaim 6084, wherein confrolling at least one condition in the formation comprises confrolling a temperature gradient within at least a portion ofthe formation.
6088. The method ofclaim 6084, wherein controlling at least one condition in the formation comprises confrolling a temperature withhi at least a portion ofthe formation.
6089. The method ofclaim 6084, wherein controlling at least one condition in the formation comprises confrolling a heating rate within at least a portion ofthe foimation.
6090. The method ofclaim 6084, further comprising separating the produced fluids into one or more fractions using distillation.
6091. The method of claim 6084, further comprising separating the produced fluids into one or more fractions using condensation.
6092. The method ofclaim 6084, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and further comprising providing the heart cut to an exfraction unit, and separating at least some thiophenes from the heart cut.
6093. The method of claim 6084, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a thiophenes fraction, and further comprising providing the thiophenes fraction to an extraction unit, and separating at least some thiophenes from the thiophenes fraction.
6094. The method ofclaim 6084, wherehi the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
6095. The method of claim 6084, wherein the formation fluids are produced from the formation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6096. The method of claim 6084, wherein at least one heat source comprises a heater.
6097. A method of separating thiophenes from fluids produced from a relatively low peπneability formation containing heavy hydrocarbons, comprising: separating thiophenes from the produced fluids, wherein the produced fluids are obtained by: providing heat from one or more heat sources to at least a portion ofthe foimation; allowing the heat to transfer from at least one or more heat sources to a selected section ofthe formation; and producing fluids from the formation wherein the produced fluids comprise thiophenes.
6098. The method ofclaim 6097, further comprising confrolling a fluid pressure within at least a portion ofthe formation.
6099. The method of claim 6097, further comprising controlling a temperature gradient within at least a portion ofthe formation.
6100. The method ofclaim 6097, further comprising conttoUing a temperature within at least a portion ofthe foπnation.
6101. The method ofclaim 6097, further comprising controlling a heating rate within at least a portion ofthe fonnation
6102. The method of claim 6097, wherein separating at least some thiophenes from the produced fluids further comprises separating the produced fluids into one or more fractions using distillation.
6103. The method ofclaim 6097, wherein separating at least some thiophenes from the produced fluids further comprises separating the produced fluids into one or more fractions using condensation.
6104. The method of claim 6097, wherein separating at least some thiophenes from the produced fluids further comprises separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and extracting at least a portion ofthe thiophenes from the heart cut.
6105. The method of claim 6097, wherein separating at least some thiophenes from the produced fluids further comprises removing a naphtha fraction from the produced fluids, and separating at least a portion ofthe thiophenes from the naphtha fraction.
6106. The method ofclaim 6097, wherein separating at least some thiophenes from the produced fluids further comprises removing an thiophenes fraction from the produced fluids, and separating at least a portion ofthe thiophenes from the thiophenes fraction.
6107. The method of claim 6097, wherein separating the thiophenes from the produced fluids further comprises removing thiophenes using distillation.
6108. The method of claim 6097, wherein separating the thiophenes from the produced fluids further comprises removing thiophenes using crystallization.
6109. The method ofclaim 6084, wherein the heat provided from at least one heat source is fransfened to the formation substantially by conduction.
6110. The method of claim 6084, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the foimation is at least about 0.5 bars absolute.
6111. The method of clahn 6084, wherein at least one heat source comprises a heater.
6112. A method of treating a relatively low permeability formation containing heavy hydrocarbons comprising: providing a barrier to at least a portion ofthe formation to inhibit migration of fluids into or out of a freatment area ofthe foimation; providing heat from one or more heat sources to the freatment area; allowing the heat to transfer from the treatment area to a selected section ofthe formation; and producing fluids from the formation.
6113. The method of claim 6112, wherein the heat provided from at least one of the one or more heat sources is fransfened to at least a portion ofthe foimation substantially by conduction.
6114. The method of claim 6112, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the fonnation is at least about 0.5 bars absolute.
6115. The method of claim 6112, wherein at least one of the one or more of the heat sources comprises a heater.
6116. The method of claim 6112, further comprising hydraulically isolating the treatment area from a sunounding portion of the formation.
6117. The method ofclaim 6112, further comprising pyrolyzing at least a portion of hydrocarbon containing material within the treatment area.
6118. The method of claim 6112, further comprising generating synthesis gas in at least a portion of the treatment area.
6119. The method ofclaim 6112, further comprising controlling a pressure within the freatment area.
6120. The method ofclaim 6112, further comprising controlling a temperature within the freatment area.
6121. The method of claim 6112, further comprising confrolling a heating rate within the freatment area.
6122. The method ofclaim 6112, further comprising controlling an amount of fluid removed from the freatment area.
6123. The method of claim 6112, wherein at least section of the banier comprises one or more sulfur wells.
6124. The method ofclaim 6112, wherein at least section ofthe banier comprises one or more dewatering wells.
6125. The method ofclaim 6112, wherein at least section ofthe banier comprises one or more injection wells and one or more dewatering wells.
6126. The method ofclaim 6112, wherein providing a banier comprises: providing a circulating fluid to the a portion ofthe formation sunounding the treatment area; and removing the circulating fluid proximate the freatment area.
6127. The method ofclaim 6112, wherein at least section ofthe banier comprises a ground cover on a surface of the earth.
6128. The method ofclaim 6127, wherein at least section ofthe ground cover is sealed to a surface ofthe earth.
6129. The method ofclaim 6112, further comprising inhibiting a release of formation fluid to the earth's atmosphere with a ground cover; and freezing at least a portion ofthe ground cover to a surface ofthe earth.
6130. The method of claim 6112, further comprising inhibiting a release of formation fluid to the earth's atmosphere.
6131. The method ofclaim 6112, further comprising inhibiting fluid seepage from a surface ofthe earth into the freatment area.
6132. The method ofclaim 6112, wherein at least a section ofthe banier is naturally occuning.
6133. The method ofclaim 6112, wherein at least a section ofthe banier comprises a low temperature zone.
6134. The method ofclaim 6112, wherein at least a section ofthe banier comprises a frozen zone.
6135. The method of claim 6112, wherein the banier comprises an installed portion and a naturally occuning portion.
6136. The method of claim 6112, further comprising: hydraulically isolating the treatment area from a sunounding portion ofthe formation; and maintaining a fluid pressure within the freatment area at a pressure greater than about a fluid pressure within the sunounding portion ofthe foπnation.
6137. The method of claim 6112, wherein at least a section of the banier comprises an impermeable section of the formation.
6138. The method of claim 6112, wherein the banier comprises a self-sealing portion.
6139. The method of claim 6112, wherein the one or more heat sources are positioned at a distance greater than about 5 m from the banier.
6140. The method ofclaim 6112, wherein at least one ofthe one or more heat sources is positioned at a distance less than about 1.5 m from the banier.
6141. The method ofclaim 6112, wherein at least a portion ofthe banier comprises a low temperature zone, and further comprising lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.
6142. The method ofclaim 6112, wherein the banier comprises a banier well and further comprising positioning at least a portion ofthe banier well below a water table ofthe foimation.
6143. The method of claim 6112, wherein the freatment area comprises a ffrst freatment area and a second freatment area, and further comprising: freating the first freatment area using a first freatment process; and freating the second treatment area using a second freatment process.
6144. A method of freating a relatively low peπneability foπnation containing heavy hydrocarbons in situ, comprising: providing a refrigerant to a plurality of banier wells placed in a portion ofthe formation; establishing a frozen banier zone to inhibit migration of fluids into or out of a freatment area; providing heat from one or more heat sources to the treatment area; allowing the heat to transfer from the freatment area to a selected section; and producing fluids from the formation.
6145. The method ofclaim 6144, wherein the heat provided from at least one ofthe one or more heat sources is transfened to at least a portion ofthe fomiation substantially by conduction.
6146. The method ofclaim 6144, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6147. The method ofclaim 6144, wherein at least one ofthe one or more ofthe heat sources comprises a heater.
6148. The method of claim 6144, further comprising controlling a fluid pressure within the freatment area;
6149. The method ofclaim 6144, wherein the frozen banier zone is proximate the treatment area ofthe formation
6150. The method ofclaim 6144, further comprising hydraulically isolating the treatment area from a sunounding portion ofthe formation.
6151. The method of claim 6144, further comprising thermally isolating the treatment area from a sunounding portion ofthe formation
6152. The method of claim 6144, further comprising maintaining the fluid pressure above a hydrostatic pressure ofthe foimation
6153. The method ofclaim 6144, further comprising removing liquid water from at least a portion ofthe freatment area.
6154. The method ofclaim 6144, wherein the treatment area is below a water table ofthe formation.
6155. The method ofclaim 6144, wherein at least one banier well ofthe plurality of banier wells comprises a conosion inhibitor.
6156. The method of claim 6144, wherein heating is initiated after foimation ofthe frozen banier zone.
6157. The method ofclaim 6144, wherein the refrigerant comprises one or more hydrocarbons.
6158. The method of claim 6144, wherein the refrigerant comprises propane. '
6159. The method ofclaim 6144, wherein the refrigerant comprises isobutane.
6160. The method of claim 6144, wherein the refrigerant comprises cyclopentane.
6161. The method of claim 6144, wherein the refrigerant comprises ammonia.
6162. The method ofclaim 6144, wherehi the refrigerant comprises an aqueous salt mixture.
6163. The method of claim 6144, wherein the refrigerant comprises an organic acid salt.
6164. The method of claim 6144, wherein the refrigerant comprises a salt of an organic acid.
6165. The method of claim 6144, wherein the refrigerant comprises an organic acid.
6166. The method ofclaim 6144, wherein the refrigerant has a freezing point of less than about minus 60 degrees Celsius.
6167. The method ofclaim 6144, wherein the refrigerant comprises calcium chloride.
6168. The method ofclaim 6144, wherein the refrigerant comprises lithium chloride.
6169. The method ofclaim 6144, wherein the refrigerant comprises liquid nifrogen.
6170. The method of claim 6144, wherein the refrigerant is provided at a temperature of less than about minus 50 degrees Celsius.
6171. The method of claim 6144, wherein the refrigerant comprises carbon dioxide.
6172. The method of claim 6144, wherein at least one ofthe plurality of banier wells is located along sfrike of a hydrocarbon containing portion ofthe foimation.
6173. The method of claim 6144, wherein at least one of the plurality of banier wells is located along dip of a hydrocarbon containing portion ofthe formation.
6174. The method ofclaim 6144, wherein the one or more heat sources are placed greater than about 5 m from a frozen banier zone.
6175. The method ofclaim 6144, wherein at least one ofthe one or more heat sources is positioned less than about 1.5 m from a frozen banier zone.
6176. The method ofclaim 6144, wherein a distance between a center of at least one banier well and a center of at least one adjacent banier well is greater than about 2 m.
6177. The method of claim 6144, further comprising desorbing methane from the formation.
6178. The method ofclaim 6144, further comprising pyrolyzing at least some hydrocarbon containing material within the freatment area.
6179. The method ofclaim 6144, further comprising producing synthesis gas from at least a portion ofthe formation.
6180. The method ofclaim 6144, further comprising: providing a solvent to the treatment area such that the solvent dissolves a component in the treatment area; and removing the solvent from the treatment area, wherehi the removed solvent comprises the component.
6181. The method of claim 6144, further comprising sequestering a compound in at least a portion of the freatment area.
6182. The method of clahn 6144, further comprising thawing at least a portion ofthe frozen banier zone; and wherein material in a thawed banier zone area is substantially unaltered by the application of heat.
6183. The method of claim 6144, wherein a location ofthe frozen banier zone has been selected using a flow rate of groundwater and wherein the selected groundwater flow rate is less than about 50 m/day.
6184. The method of claim 6144, further comprising providing water to the frozen banier zone.
6185. The method ofclaim 6144, further comprising positioning one or more monitoring wells outside the frozen banier zone, and then providing a tracer to the freatment area, and then monitoring for movement ofthe tracer at the monitoring wells.
6186. The method of claim 6144, further comprising: positioning one or more monitoring wells outside the frozen banier zone; then providing an acoustic pulse to the treatment area; and then monitoring for the acoustic pulse at the monitoring wells.
6187. The method ofclaim 6144, wherein a fluid pressure within the treatment area can be controlled at fluid pressures different from a fluid pressure that exists in a sunounding portion ofthe formation.
6188. The method ofclaim 6144, wherein fluid pressure within an area at least partially bounded by the frozen banier zone can be confrolled higher than, or lower than, hydrostatic pressures that exist in a sunounding portion of the formation.
6189. The method ofclaim 6144, further comprising controlling compositions of fluids produced from the formation by confrolling the fluid pressure within an area at least partially bounded by the frozen banier zone.
6190. The method of claim 6144, wherein a portion of at least one ofthe plurality of banier wells is positioned below a water table ofthe foimation.
6191. A method of treating a relatively low permeability formation containing heavy hydrocarbons comprising: providing a refrigerant to one or more banier wells placed in a portion ofthe formation; establishing a low temperature zone proxhnate a treatment area ofthe foimation; providing heat from one or more heat sources to a freatment area ofthe formation; allowing the heat to fransfer from the treatment area to a selected section ofthe formation; and producing fluids from the formation.
6192. The method of claim 6191, further comprising forming a frozen banier zone within the low temperature zone, wherein the frozen barrier zone hydraulically isolates the freatment area from a sunounding portion ofthe foimation.
6193. The method of claim 6191, further comprising forming a frozen banier zone within the low temperature zone, and wherein fluid pressure within an area at least partially bounded by the frozen banier zone can be confrolled at different fluid pressures from the fluid pressures that exist outside ofthe frozen banier zone.
6194. The method of claim 6191, further comprising fonning a frozen banier zone within the low temperature zone, and wherein fluid pressure within an area at least partially bounded by the frozen banier zone can be controlled higher than, or lower than, hydrostatic pressures that exist outside ofthe frozen banier zone.
6195. The method of claim 6191, further comprising forming a frozen banier zone within the low temperature zone, and wherein fluid pressure within an area at least partially bounded by the frozen banier zone can be confrolled higher than, or lower than, hydrostatic pressures that exist outside ofthe frozen banier zone, and further comprising controlling compositions of fluids produced from the formation by controlling the fluid pressure within the area at least partially bounded by the frozen banier zone.
6196. The method of claim 6191, further comprising thawing at least a portion of the low temperature zone, wherein material within the thawed portion is substantially unaltered by the application of heat such that the structural integrity ofthe relatively low permeability formation containing heavy hydrocarbons is substantially maintained.
6197. The method of claim 6191, wherein an inner boundary ofthe low temperature zone is determined by monitoring a pressure wave using one or more piezometers.
6198. The method ofclaim 6191, further comprising confrolling a fluid pressure within the treatment area at a pressure less than about a foimation fracture pressure.
6199. The method of claim 6191, further comprising positioning one or more monitoring wells outside the frozen banier zone, and then providing an acoustic pulse to the treatment area, and then monitoring for the acoustic pulse at the monitoring wells.
6200. The method ofclaim 6191, further comprising positioning a segment of at least one ofthe one or more banier wells below a water table ofthe formation.
6201. The method of claim 6191, further comprising positioning the one or more banier wells to establish a continuous low temperature zone.
6202. The method ofclaim 6191, wherein the refrigerant comprises one or more hydrocarbons.
6203. The method ofclaim 6191, wherein the refrigerant comprises propane.
6204. The method ofclaim 6191, wherein the refrigerant comprises isobutane.
6205. The method of claim 6191, wherein the refrigerant comprises cyclopentane.
6206. The method of claim 6191, wherein the refrigerant comprises ammonia.
6207. The method of claim 6191, wherein the refrigerant comprises an aqueous salt mixture.
6208. The method ofclaim 6191, wherein the refrigerant comprises an organic acid salt.
6209. The method of claim 6191, wherein the refrigerant comprises a salt of an organic acid.
6210. The method ofclaim 6191, wherein the refrigerant comprises an organic acid.
6211. The method ofclaim 6191, wherein the refrigerant has a freezing point of less than about minus 60 degrees Celsius.
6212. The method of claim 6191, wherein the refrigerant is provided at a temperature of less than about minus 50 degrees Celsius.
6213. The method of claim 6191, wherein the refrigerant is provided at a temperature of less than about minus 25 degrees Celsius.
6214. The method ofclaim 6191, wherein the refrigerant comprises carbon dioxide.
6215. The method of claim 6191, further comprising: cooling at least a portion ofthe refrigerant in an absoφtion refrigeration unit; and providing a thermal energy source to the absoφtion refrigeration unit.
6216. The method ofclaim 6191, wherein the thermal energy source comprises water.
6217. The method of claim 6191, wherein the theπnal energy source comprises steam.
6218. The method of claim 6191, wherein the thermal energy source comprises at least a portion of the produced fluids.
6219. The method ofclaim 6191, wherein the thermal energy source comprises exhaust gas.
6220. A method of treating a relatively low permeability foπnation containing heavy hydrocarbons, comprising: inhibiting migration of fluids into or out of a treatment area ofthe formation from a sunounding portion of the foπnation; providing heat from one or more heat sources to at least a portion ofthe freatment area; allowing the heat to transfer from at least the portion to a selected section ofthe formation; and producing fluids from the foπnation.
6221. The method of claim 6220, wherein the heat provided from at least one ofthe one or more heat sources is fransfened to at least a portion ofthe formation substantially by conduction.
6222. The method of claim 6220, wherein the fluids are produced from the foimation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6223. The method of claim 6220, wherein at least one ofthe one or more ofthe heat sources comprises a heater.
6224. The method of claim 6220, further comprising providing a banier to at least a portion ofthe formation.
6225. The method ofclaim 6224, wherein at least section ofthe banier comprises one or more sulfur wells.
6226. The method of claim 6224, wherein at least section ofthe banier comprises one or more pumping wells.
6227. The method ofclaim 6224, wherein at least section ofthe banier comprises one or more injection wells and one or more pumping wells.
6228. The method of claim 6224, wherein at least a section ofthe banier is naturally occuning.
6229. The method of claim 6220, further comprises establishing a banier in at least a portion ofthe foπnation, and wherein heat is provided after at least a portion ofthe banier has been established.
6230. The method ofclaim 6220, further comprising establishing a banier in at least a portion ofthe formation, and wherein heat is provided while at least a portion ofthe banier is being established.
6231. The method of claim 6220, further comprising providing a banier to at least a portion ofthe formation, and wherein heat is provided before the banier is established.
6232. The method ofclaim 6220, further comprising controlling an amount of fluid removed from the freatment area.
6233. The method ofclaim 6220, wherein isolating a freattnent area from a sunounding portion ofthe formation comprises providing a low temperature zone to at least a portion ofthe foimation.
6234. The method ofclaim 6220, wherein isolating a treatment area from a sunounding portion ofthe formation comprises providing a frozen banier zone to at least a portion ofthe formation.
6235. The method ofclaim 6220, wherein isolating a treatment area from a sunounding portion ofthe formation comprises providing a grout wall.
6236. The method of clahn 6220, further comprising inhibiting flow of water into or out of at least a portion of a treatment area.
6237. The method of claim 6220, further comprising: providing a material to the treatment area; and storing at least some ofthe material within the freatment area.
6238. A method of treating a relatively low peπneability fonnation containing heavy hydrocarbons, comprising: providing a barrier to a portion ofthe foπnation, wherein the portion has previously undergone an in situ conversion process; and inhibiting migration of fluids into and out ofthe converted portion to a sunounding portion ofthe formation.
6239. The method of claim 6238, wherein the banier comprises a frozen banier zone.
6240. The method ofclaim 6238, wherein the banier comprises a low temperature zone.
6241. The method ofclaim 6238, wherein the banier comprises a sealing mineral phase.
6242. The method of claim 6238, wherein the banier comprises a sulfur banier.
6243. The method of claim 6238, wherein the contaminant comprises a metal.
6244. The method ofclaim 6238, wherein the contaminant comprises organic residue.
6245. A method of freating a relatively low penneability foimation containing heavy hydrocarbons, comprising: infroducing a first fluid into at least a portion ofthe formation, wherein the portion has previously undergone an in situ conversion process; producing a mixture ofthe ffrst fluid and a second fluid from the formation; and providing at least a portion ofthe mixture to an energy producing unit.
6246. The method of claim 6245, wherein the ffrst fluid is selected to recover heat from the foπnation.
6247. The method of claim 6245, wherein the first fluid is selected to recover heavy compounds from the formation.
6248. The method ofclaim 6245, wherein the first fluid is selected to recover hydrocarbons from the fonnation.
6249. The method of clahn 6245, wherein the mixture comprises an oxidizable heat recovery fluid.
6250. The method of claim 6245, wherein producing the mixture remediates the portion ofthe foimation by removing contaminants from the formation in the mixture.
6251. The method of clahn 6245, wherein the first fluid comprises a hydrocarbon fluid.
6252. The method of claim 6245, wherein the first fluid comprises methane.
6253. The method of claim 6245, wherein the first fluid comprises ethane.
6254. The method of claim 6245, wherein the first fluid comprises molecular hydrogen.
6255. The method of claim 6245, wherein the energy producing unit comprises a turbine, and generating electricity by passing mixture through the energy producing unit.
6256. The method of claim 6245, further comprising combusting mixture within the energy producing unit.
6257. The method ofclaim 6245, further comprising inhibiting spread ofthe mixttire from the portion ofthe formation with a banier.
6258. A method of freating a relatively low peπneability formation containing heavy hydrocarbons, comprising: providing a first fluid to at least a portion of a freatment area, wherein the freatment area includes one or more components; producing a fluid from the foimation wherein the produced fluid comprises first fluid and at least some of the one or more components; and wherein the freatment area is obtained by providing heat from heat sources to a portion of a relatively low permeability foπnation containing heavy hydrocarbons to convert a portion of hydrocarbons to desired products and removing a portion ofthe desfred hydrocarbons from the foimation.
6259. The method of claim 6258, wherein the first fluid comprises water.
6260. The method ofclaim 6258, wherein the first fluid comprises carbon dioxide.
6261. The method ofclaim 6258, wherein the first fluid comprises steam.
6262. The method ofclaim 6258, wherein the ffrst fluid comprises afr.
6263. The method ofclaim 6258, wherein the first fluid comprises a combustible gas.
6264. The method of clahn 6258, wherein the first fluid comprises hydrocarbons.
6265. The method of clahn 6258, wherein the first fluid comprises methane.
6266. The method ofclaim 6258, wherein the first fluid comprises ethane.
6267. The method ofclaim 6258, wherein the first fluid comprises molecular hydrogen.
6268. The method ofclaim 6258, wherein the first fluid comprises propane.
6269. The method ofclaim 6258, further comprising reacting a portion ofthe contaminants with the first fluid.
6270. The method of claim 6258, further comprising providing at least a portion ofthe produced fluid to an energy generating unit to generate electticity.
6271. The method ofclaim 6258, further comprising providing at least a portion ofthe produced fluid to a combustor.
6272. The method ofclaim 6258, wherein a frozen banier defines at least a segment of a banier within the formation, allowing a portion ofthe frozen banier to thaw prior to providing the first fluid to the treatment area, and providing at least some ofthe first fluid into the thawed portion ofthe barrier.
6273. The method of claim 6258, wherein a volume of first fluid provided to the freatment area is greater than about one pore volume ofthe treatment area.
6274. The method of claim 6258, further comprising separating contaminants from the first fluid.
6275. A method of recovering thermal energy from a heated relatively low permeability foπnation containing heavy hydrocarbons, comprising: injecting a heat recovery fluid into a heated portion ofthe formation; allowing heat from the portion ofthe foimation to transfer to the heat recovery fluid; and producing fluids from the foimation.
6276. The method of claim 6275, wherein the heat recovery fluid comprises water.
6277. The method of claim 6275, wherein the heat recovery fluid comprises saline water.
6278. The method of claim 6275, wherein the heat recovery fluid comprises non-potable water.
6279. The method ofclaim 6275, wherein the heat recovery fluid comprises alkaline water.
6280. The method of claim 6275, wherein the heat recovery fluid comprises hydrocarbons.
6281. The method of claim 6275, wherein the heat recovery fluid comprises an inert gas.
6282. The method of claim 6275, wherein the heat recovery fluid comprises carbon dioxide.
6283. The method of claim 6275, wherein the heat recovery fluid comprises a product stteam produced by an in situ conversion process.
6284. The method of claim 6275, further comprising vaporizing at least some ofthe heat recovery fluid.
6285. The method ofclaim 6275, wherein an average temperature ofthe portion ofthe post treatment foimation prior to injection of heat recovery fluid is greater than about 300°C.
6286. The method ofclaim 6275, further comprising providing the heat recovery fluid to the formation through a heater well.
6287. The method ofclaim 6275, wherehi fluids are produced from one or more production wells in the foimation.
6288. The method ofclaim 6275, further comprising providing at least some ofthe produced fluids to a treatment process in a section ofthe formation.
6289. The method ofclaim 6275, further comprising recovering at least some ofthe heat from the produced fluids.
6290. The method ofclaim 6275, further comprising providing at least some ofthe produced fluids to a power generating unit.
6291. The method ofclaim 6275, further comprising providing at least some ofthe produced fluids to a heat exchange mechanism.
6292, The method ofclaim 6275, further comprising providing at least some ofthe produced fluids to a steam cracking unit.
6293. The method of clahn 6275, further comprising providing at least some of the produced fluids to a hydrofreating unit.
6294. The method ofclaim 6275, further comprising providing at least some ofthe produced fluids to a distillation column.
6295. The method of claim 6275, wherein the heat recovery fluid comprises carbon dioxide, and wherein at least some ofthe carbon dioxide is adsorbed onto the surface of carbon in the formation.
6296. The method of claim 6275, wherein the heat recovery fluid comprises carbon dioxide, and further comprising: allowing at least some hydrocarbons within the formation to desorb from the formation; and producing at least some ofthe desorbed hydrocarbons from the formation.
6297. The method of claim 6275, further comprising providing at least some ofthe produced fluids to a freatment process in a section ofthe formation.
6298. The method of claim 6275, wherein the heat recovery fluid is saline water, and further comprising: providing carbon dioxide to the portion ofthe formation; and precipitating carbonate compounds.
6299. The method of claim 6275, further comprismg reducing an average temperature ofthe foimation to a temperature less than about an ambient boiling temperature of water at a post freatment pressure.
630,0. The method of claim 6275, wherein the produced fluids comprise low molecular weight hydrocarbons.
6301. The method of claim 6275, wherein the produced fluids comprise hydrocarbons.
6302. The method of claim 6275, wherein the produced fluids comprise heat recovery fluid.
6303. A method of freating a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to fransfer from the one or more heat sources to a selected section ofthe formation; controlling at least one condition within the selected section; producing a mixture from the formation; and wherein at least the one condition is controlled such that the mixture comprises a carbon dioxide emission level less than about a selected carbon dioxide emission level.
6304. The method ofclaim 6303, wherein the heat provided from at least one heat source is fransfened to at least a portion ofthe foimation substantially by conduction.
6305. The method ofclaim 6303, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6306. The method ofclaim 6303, wherein at least one ofthe one or more ofthe heat sources comprises a heater.
6307. The method ofclaim 6303, wherein the selected carbon dioxide emission level is less than about 5.6 x 10-8 kg C02 produced for every Joule of energy.
6308. The method ofclaim 6303, wherein the selected carbon dioxide emission level is less than about 1.6 x 10-8 kg C02 produced for every Joule of energy.
6309. The method ofclaim 6303, wherein the selected carbon dioxide emission level is less than about 1.6 x 10- 10 kg C02 produced for eveiy Joule of energy.
6310. The method ofclaim 6303, further comprising blending the mixture with a fluid to form a blended product comprising a carbon dioxide emission level less than about the selected baseline carbon dioxide emission level.
6311. The method ofclaim 6303, wherein confrolling conditions within a selected section comprises confrolling a pressure within the selected section.
6312. The method ofclaim 6303, wherein confrolling conditions within a selected section comprises controlling an average temperature within the selected section.
6313. The method of claim 6303, wherein confrolling conditions within a selected section comprises controlling an average heating rate within the selected section.
6314. A method for producing molecular hydrogen from a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to at least one portion ofthe formation such that carbon dioxide production is minimized; allowing the heat to fransfer from the one or more heat sources to a selected section ofthe foimation; producing a mixture comprising molecular hydrogen from the formation; and controlling the heat from the one or more heat sources to enhance production of molecular hydrogen.
6315. The method of claim 6314, wherein the heat provided from at least one heat source is transfened to at least a portion ofthe formation substantially by conduction.
6316. The method ofclaim 6314, wherein at least one ofthe one or more ofthe heat sources comprises a heater.
6317. The method of claim 6401 , wherein the mixture is produced from the fonnation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6318. The method ofclaim 6314, wherein confrolling the heat comprises confroUing a temperature proximate the production wellbore at or above a decomposition temperature of methane.
6319. The method ofclaim 6314, wherein heat is generated by oxidizing molecular hydrogen in at least one heat source.
6320. The method of claim 6314, wherein heat is generated by electricity produced from wind power.
6321. The method of claim 6314, wherein heat is generated from elecfrical power.
6322. The method of claim 6314, wherein the heat sources form an anay of heat sources.
6323. The method of claim 6314, further comprising heating at least a portion ofthe selected section ofthe formation to greater than about 600 °C.
6324. The method ofclaim 6314, wherein the produced mixture is produced from a production wellbore, and further comprising controlling the heat from one or more heat sources such that the temperature in the formation proximate the production wellbore is at least about 600 °C.
6325. The method ofclaim 6314, wherein the produced mixture is produced from a production wellbore, and further comprising heating at least a portion ofthe formation with a heater proximate the production wellbore.
6326. The method of claim 6314, further comprishig recycling at least a portion ofthe produced molecular hydrogen into the formation.
6327. The method of claim 6314, wherein the produced mixture comprises methane, and ftirther comprising oxidizing at least a portion ofthe methane to provide heat to the foimation.
6328. The method ofclaim 6314, wherein controlling the heat comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
6329. The method of claim 6314, wherein the one or more heat sources comprise one or more electrical heaters powered by a fuel cell, and wherein at least a portion ofthe molecular hydrogen in the produced mixture is used in the fuel cell.
6330. The method of claim 6314, further comprising confrolling a pressure within at least a majority ofthe selected section ofthe foπnation.
6331. The method ofclaim 6314, further comprising confrolling the heat such that an average heating rate ofthe selected section is less than about 3 °C per day during pyrolysis.
6332. The method ofclaim 6314, wherein allowing the heat to ttansfer from the one or more heat sources to the selected section comprises fransfening heat substantially by conduction.
6333. The method ofclaim 6314, wherein at least 50% by volume ofthe produced mixture comprises molecular hydrogen.
6334. The method ofclaim 6314, wherein less than about 3.3 x 10-8 kg C02 is produced for every Joule of energy in the produced mixture.
6335. The method ofclaim 6314, wherein less than about 1.6 x 10-10 kg C02 is produced for every Joule of energy in the produced mixture.
6336. The method ofclaim 6314, wherein less than about 3.3 x 10-10 kg C02 is produced for every Joule of energy in the produced mixture.
6337. The method ofclaim 6314, wherein the produced mixture is produced from a production wellbore, and further comprising controlling the heat from one or more heat sources such that the temperature in the formation proximate the production wellbore is at least about 500 °C.
6338. The method of claim 6314, wherein the produced mixture comprises methane and molecular hydrogen, and further comprising: separating at least a portion ofthe molecular hydrogen from the produced mixture; and providing at least a portion ofthe separated mixture to at least one ofthe one or more heat sources for use as fuel.
6339. The method ofclaim 6314, wherein the produced mixture comprises methane and molecular hydrogen, and further comprising: separating at least a portion ofthe molecular hydrogen from the produced mixture; and providing at least some ofthe molecular hydrogen to a fuel cell to generate electricity.
6340. A method for producing methane from a relatively low permeability foπnation containing heavy hydrocarbons in situ while minimizing production of C02, comprising:
providing heat from one or more heat sources to at least one portion ofthe formation such that C02 production is minimized; allowing the heat to fransfer from the one or more heat sources to a selected section ofthe foπnation; producing a mixture comprising methane from the formation; and confrolling the heat from the one or more heat sources to enhance production of methane.
6341. The method ofclaim 6340, wherein the heat provided from at least one ofthe one or more heat source is transfened to at least a portion ofthe foπnation substantially by conduction.
6342. The method ofclaim 6340, wherein at least one ofthe one or more ofthe heat sources comprises a heater.
6343. The method ofclaim 6340, wherein controlling the heat comprises confrolling a temperature proximate the production wellbore at or above a decomposition temperature of ethane.
6344. The method ofclaim 6340, wherein heat is generated by oxidizing methane in at least one heat source.
6345. The method ofclaim 6340, wherein heat is generated by electticity produced from wind power.
6346. The method of claim 6340, wherein heat is generated from electtical power.
6347. The method ofclaim 6340, wherein the heat sources form an anay of heat sources.
6348. The method ofclaim 6340, further comprising heating at least a portion ofthe selected section ofthe formation to greater than about 400 °C.
6349. The method of claim 6340, wherein the produced mixture is produced from a production wellbore, and further comprising confrolling the heat from one or more heat sources such that the temperature in the foimation proximate the production wellbore is at least about 400 °C.
6350. The method ofclaim 6340, wherein the produced mixture is produced from a production wellbore, and further comprising heating at least a portion ofthe formation with a heater proximate the production wellbore.
6351. The method ofclaim 6340, further comprising recycling at least a portion ofthe produced methane into the formation.
6352. The method ofclaim 6340, wherein the produced mixture comprises methane, and further comprising oxidizing at least a portion ofthe methane to provide heat to the formation.
6353. The method ofclaim 6340, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section ofthe formation.
6354. The method of claim 6340, wherein confrolling the heat comprises maintaining a temperature within the selected section within a pyrolysis temperature range.
6355. The method ofclaim 6340, wherein the one or more heat sources comprise one or more electrical heaters powered by a fuel cell, and wherein at least a portion ofthe molecular hydrogen in the produced mixture is used in the fuel cell.
6356. The method ofclaim 6340, further comprismg controlling a pressure within at least a majority ofthe selected section ofthe formation.
6357. The method ofclaim 6340, further comprising controlling the heat such that an average heathig rate ofthe selected section is less than about 3 °C per day during pyrolysis.
6358. The method of clahn 6340, wherein allowing the heat to fransfer from the one or more heat sources to the selected section comprises transferring heat substantially by conduction.
6359. The method ofclaim 6340, wherein less than about 8.4 x 10-8 kg C02 is produced for every Joule of energy in the produced mixture.
6360. The method ofclaim 6340, wherein less than about 7.4 x 10-8 kg C02 is produced for every Joule of energy in the produced mixture.
6361. The method ofclaim 6340, wherein less than about 5.6 x 10-8 kg C02 is produced for every Joule of energy in the produced mixture.
6362. A method for upgrading hydrocarbons in a relatively low permeability formation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to a portion ofthe formation; allowing the heat to ttansfer from the first portion to a selected section ofthe formation; providing hydrocarbons to the selected section; and producing a mixture from the formation, wherein the mixture comprises hydrocarbons that were provided to the selected section and upgraded in the formation.
6363. The method of claim 6362, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the foimation is at least about 0.5 bars absolute.
6364. The method ofclaim 6362, wherehi the heat provided from at least one heat source is fransfened to at least a portion ofthe formation substantially by conduction.
6365. The method ofclaim 6362, wherein at least one ofthe one or more ofthe heat sources comprises a heater.
6366. The method ofclaim 6362, wherein the provided hydrocarbons comprise heavy hydrocarbons.
6367. The method ofclaim 6362, wherein the provided hydrocarbons comprise naphtha.
6368. The method ofclaim 6362, wherein the provided hydrocarbons comprise asphaltenes.
6369. The method ofclaim 6362, wherehi the provided hydrocarbons comprise crade oil.
6370. The method ofclaim 6362, wherein the provided hydrocarbons comprise surface mined tar from relatively permeable formations.
6371. The method ofclaim 6362 wherein the provided hydrocarbons comprise an emulsion produced from a relatively permeable formation, and further comprising providing the produced emulsion to the first portion after a temperature in the selected section is greater than about a pyrolysis temperature.
6372. The method of clahn 6362, further comprising providing steam to the selected section.
6373. The method of claim 6362, further comprising: producing foimation fluids from the formation; separating the produced formation fluids into one or more components; and wherein the provided hydrocarbons comprise at least one ofthe one or more components.
6374. The method ofclaim 6362, further comprising: providing steam to the selected section, wherein the provided hydrocarbons are mixed with the steam; and controlling an amount of steam such that a residence time ofthe provided hydrocarbons within the selected section is controlled.
6375. The method ofclaim 6362, wherein the produced mixture comprises upgraded hydrocarbons, and ftirther comprising confrolling a residence time ofthe provided hydrocarbons within the selected section to control a molecular weight disttibution within the upgraded hydrocarbons.
6376. The method ofclaim 6362, wherein the produced mixture comprises upgraded hydrocarbons, and further comprising confrolling a residence time ofthe provided hydrocarbons in the selected section to confrol an API gravity ofthe upgraded hydrocarbons.
6377. The method ofclaim 6362, further comprising steam cracking in at least a portion ofthe selected section.
6378. The method ofclaim 6362, wherein the provided hydrocarbons are produced from a second portion ofthe foimation.
6379. The method of claim 6362, further comprising allowing some ofthe provided hydrocarbons to crack in the foimation to generate upgraded hydrocarbons.
6380. The method of claim 6362, further comprising controlling a temperature ofthe ffrst portion ofthe formation by confrolling a pressure and a temperature within at least a majority ofthe selected section ofthe foimation, wherein the pressure is conttolled as a function of temperature, or the temperature is conttolled as a function of pressure.
6381. The method of claim 6362, further comprising confrolling a pressure within at least a majority ofthe selected section ofthe formation.
6382. The method ofclaim 6362, wherein a temperature in the first portion is greater than about a pyrolysis temperature.
6383. The method of claim 6362, further comprising: confrolling the heat such that a temperature ofthe ffrst portion is greater than about a pyrolysis temperature of hydrocarbons; and producing at least some ofthe provided hydrocarbons from the first portion ofthe formation.
6384. The method of claim 6362, further comprising producing at least some ofthe provided hydrocarbons from a second portion of the formation.
6385. The method of claim 6362, further comprising: confrolling the heat such that a temperature of a second portion is less than about a pyrolysis temperature of hydrocarbons; and producing at least some ofthe provided hydrocarbons from the second portion ofthe formation..
6386. The method of claim 6362, further comprismg producing at least some ofthe provided hydrocarbons from a second portion ofthe foimation and wherein a temperature ofthe second portion is about an ambient temperature ofthe formation.
6387. The method of claim 6362, wherein the upgraded hydrocarbons are produced from a production well and wherehi the heat is confrolled such that the upgraded hydrocarbons can be produced from the formation as a vapor.
6388. A method for producing methane from a relatively low penneability foπnation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least one portion ofthe formation; allowing the heat to fransfer from the one or more heat sources to a selected section ofthe foimation; providing hydrocarbon fluids to at least the selected section ofthe formation; and producing mixture comprising methane from the foimation.
6389. The method ofclaim 6388, wherein the heat provided from at least one heat source is fransfened to at least a portion ofthe formation substantially by conduction.
6390. The method ofclaim 6388, wherein at least one ofthe one or more ofthe heat sources comprises a heater.
6391. The method ofclaim 6388, further comprising controlling heat from at least one ofthe heat sources to enhance production of methane from the hydrocarbon fluids.
6392. The method ofclaim 6388, further comprising confrolling a temperature within at least a selected section in a range to from greater than about 400 °C to less than about 600 °C.
6393. The method ofclaim 6388, further comprising cooling the mixture to inhibit further reaction ofthe methane.
6394. The method ofclaim 6388, further comprising controlling at least some condition in the formation to enhance production of methane.
6395. The method of claim 6388, further comprising adding water to the formation.
6396. The method ofclaim 6388, further comprising separating at least a portion ofthe methane from the mixture and recycling at least some ofthe separated mixture to the formation.
6397. The method ofclaim 6388, further comprising cracking the hydrocarbon fluids to form methane.
6398. The method ofclaim 6388, wherein the mixture is produced from the foπnation through a production well, and wherein the heat is conttolled such that the mixture can be produced from the formation as a vapor.
6399. The method ofclaim 6388, wherein the mixture is produced from the formation through a production well, and further comprising heating a wellbore ofthe production well to inhibit condensation ofthe mixture within the wellbore.
6400. The method ofclaim 6388, wherein the mixture is produced from the formation through a production well, wherein a wellbore ofthe production well comprises a heater element configured to heat the formation adjacent to the wellbore, and further comprising heating the formation with the heater element to produce the mixture.
6401. A method for hydrotreating a fluid in a heated formation in situ, comprising: providing heat from one or more heat sources to at least one portion ofthe formation; allowing the heat to fransfer from the one or more heat sources to a selected section ofthe formation; providing a fluid to the selected section; confrolling a H2 partial pressure in the selected section ofthe foimation; hydrotreating at least some ofthe fluid in the selected section; and producing a mixture comprising hydrotteated fluids from the formation.
6402. The method ofclaim 6401, wherein the mixture is produced from the foimation when a partial pressure of hydrogen in the selected section is at least about 0.5 bars absolute.
6403. The method of claim 6401 , wherein the heat provided from at least one of the one or more heat source is transfened to at least a portion ofthe formation substantially by conduction.
6404. The method ofclaim 6401, wherein at least one ofthe one or more ofthe heat sources comprises a heater.
6405. The method ofclaim 6401, further comprising providing hydrogen to the selected section ofthe formation.
6406. The method of claim 6401 , further comprising controlling the heat such that a temperature within the selected section is in a range from about 200 °C to about 450 °C.
6407. The method of clahn 6401 , wherein the provided fluid comprises an olefin.
6408. The method of claim 6401 , wherein the provided fluid comprises pitch.
6409. The method ofclaim 6401,wherein the provided fluid comprises oxygenated compounds.
6410. The method ofclaim 6401, wherein the provided fluid comprises sulfur containing compounds.
6411. The method of claim 6401 , wherein the provided fluid comprises nifrogen containing compounds.
6412. The method of claim 6401 , wherein the provided fluid comprises crade oil.
6413. The method of claim 6401 , wherein the provided fluid comprises synthetic crade oil.
6414. The method of claim 6401 , wherein the produced mixture comprises a hydrocarbon mixture.
6415. The method of claim 6401 , wherein the produced mixture comprises less than about 1 % by weight ammonia.
6416. The method ofclaim 6401, wherein the produced mixture comprises less than about 1% by weight hydrogen sulfide.
6417. The method of clahn 6401 , wherein the produced mixture comprises less than about 1 % oxygenated compounds.
6418. The method of claim 6401 , further comprising producing the mixture from the formation through a production well, wherein the heating is controlled such that the mixttire can be produced from the formation as a vapor.
6419. A method for producing hydrocarbons from a heated formation in situ, comprising: providing heat from one or more heat sources to at least one portion ofthe foimation; allowmg the heat to fransfer from the one or more heat sources to a selected section ofthe formation such that at least some ofthe selected section comprises a temperature profile; providing a hydrocarbon mixture to the selected section; separating the hydrocarbon mixture into one or more mixtures of components; and producing the one or more mixtures of components from one or more production wells.
6420. The method ofclaim 6419, wherein the heat provided from at least one ofthe one or more heat source is fransfened to at least a portion ofthe formation substantially by conduction.
6421. The method ofclaim 6419, wherein the one or more ofthe heat sources comprise heaters.
6422. The method ofclaim 6419, wherein at least one ofthe one or more mixtures is produced from the foπnation when a partial pressure ofhydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6423. The method o claim 6419, further comprising controlling a pressure within at least a majority ofthe selected section.
6424. The method ofclaim 6419, wherein the temperature proflle extends horizontally through the formation.
6425. The method ofclaim 6419, wherein the temperature profile extends vertically through the formation.
6426. The method ofclaim 6419, wherein the selected section comprises a spent formation.
6427. The method ofclaim 6419, wherein the production well comprises a plurality of production wells placed at various distances from at least one ofthe one or more heat sources along the temperature gradient zone.
6428. The method ofclaim 6419, wherein the production well comprises a first production well and a second production well, further comprising: positioning the first production well at a first distance from a heat source ofthe one or more heat sources; positioning the second production well at a second distance from the heat source ofthe one or more heat sources; producing a first component ofthe one or more portions from the ffrst production well; and producing a second component of the one or more portions from the second production well.
6429. The method ofclaim 6419, further comprising heating a wellbore ofthe production well to inhibit condensation of at least the one component within the wellbore.
6430. The method of clahn 6419, wherein the one or more components comprise hydrocarbons.
6431. The method ofclaim 6419, wherein separating the one or more components further comprises: producing a low molecular weight component ofthe one or more components from the formation; allowing a high molecular weight component ofthe one or more components to remain within the formation; providing additional heat to the formation; and producing at least some ofthe high molecular weight component.
6432. The method ofclaim 6419, further comprising producing at least the one component from the formation through a production well, wherein the heating is confrolled such that the mixture can be produced from the formation as a vapor.
6433. A method of utilizing heat of a heated formation, comprising: placing a conduit in the formation; allowing heat from the foimation to fransfer to at least a portion ofthe conduit; generating a region of reaction in the conduit; allowing a material to flow through the region of reaction; reacting at least some ofthe material in the region of reaction; and producing a mixture from the conduit.
6434. The method ofclaim 6433, wherein a conduit input is located separately from a conduit output.
6435. The method of claim 6433 , wherein the conduit is configured to inhibit contact between the material and the formation.
6436. The method ofclaim 6433, wherein the conduit comprises a u-shaped conduit, and further comprising placing the u-shaped conduit within a heater well in the heated formation.
6437. The method of claim 6433, wherein the material comprises a first hydrocarbon and wherein the first hydrocarbon reacts to form a second hydrocarbon.
6438. The method ofclaim 6433, wherein the material comprises water.
6439. The method ofclaim 6433, wherein the produced mixture comprises hydrocarbons.
6440. A method for storing fluids within a relatively low peπneability formation containing heavy hydrocarbons, comprising: providing a banier to a portion ofthe foπnation to form an in situ storage area, wherein at least a portion ofthe in situ storage area has previously undergone an in situ conversion process, and wherein migration of fluids into or out ofthe storage area is inhibited; providing a material to the in situ storage area; storing at least some ofthe provided fluids within the in situ storage area; and wherein one or more conditions ofthe in situ storage area inhibits reaction within the material.
6441. The method ofclaim 6440, further comprising producing at least some ofthe stored material from the in situ storage area.
6442. The method ofclaim 6440, further comprising producing at least some ofthe stored material from the in situ storage area as a liquid.
6443. The method of claim 6440, further comprismg producing at least some ofthe stored material from the in situ storage area as a gas.
6444. The method of claim 6440, wherein the stored material is a solid, and further comprising: providing a solvent to the in situ storage area; allowing at least a portion ofthe stored material to dissolve; and producing at least some ofthe dissolved material from the in situ storage area.
6445. The method ofclaim 6440, wherein the material comprises inorganic compounds.
6446. The method ofclaim 6440, wherein the material comprises organic compounds.
6447. The method ofclaim 6440, wherein the material comprises hydrocarbons.
6448. The method of claim 6440, wherein the material comprises formation fluids
6449. The method ofclaim 6440, wherein the material comprises synthesis gas.
6450. The method of claim 6440, wherein the material comprises a solid.
6451. The method ofclaim 6440, wherein the material comprises a liquid.
6452. The method ofclaim 6440, wherein the material comprises a gas.
6453. The method ofclaim 6440, wherein the material comprises natural gas.
6454. The method ofclaim 6440, wherein the material comprises compressed afr.
6455. The method ofclaim 6440, wherein the material comprises compressed afr, and wherein the compressed afr is used as a supplement for elecfrical power generation.
6456. The method ofclaim 6440, further comprising: producing at least some ofthe material from the in situ treatment area through a production well; and heating at least a portion of a wellbore ofthe production well to inhibit condensation ofthe material within the wellbore.
6457. The method ofclaim 6440, wherein the in situ conversion process comprises pyrolysis.
6458. The method ofclaim 6440, wherein the in situ conversion process comprises synthesis gas generation.
6459. The method of claim 6440, wherein the in situ conversion process comprises solution mining.
6460. A method of filtering water within a relatively low permeability foimation containing heavy hydrocarbons comprising: providing water to at least a portion ofthe foimation, wherein the portion has previously undergone an in situ conversion process, and wherein the water comprises one or more components; removing at least one ofthe one or more components from the provided water; and producing at least some ofthe water from the formation.
6461. The method ofclaim 6460, wherein at least one ofthe one or more components comprises a dissolved cation, and further comprising: converting at least some ofthe provided water to steam; allowing at least some ofthe dissolved cation to remain in the portion o the formation; and producing at least a portion ofthe steam from the formation.
6462. The method ofclaim 6460, wherein the portion ofthe formation is above the boiling point temperature of the provided water at a pressure ofthe portion, wherein at least one ofthe one or more components comprises mineral cations, and wherein the provided water is converted to steam such that the mineral cations are deposited within the formation.
6463. The method of claim 6460 further comprising converting at least a portion ofthe provided water into steam and wherein at least one ofthe one or more components is separated from the water as the provided water is converted into steam.
6464. The method ofclaim 6460, wherein a temperature ofthe portion ofthe formation is greater than about 90 °C, and further comprising sterilizing at least some ofthe provided water within the portion ofthe formation.
6465. The method of clahn 6460, wherein a temperature within the portion is less than about a boiling temperature ofthe provided water at a fluid pressure ofthe portion.
6466. The method ofclaim 6460, further comprising remediating at least the one portion ofthe foπnation.
6467. The method ofclaim 6460, wherein the one or more components comprise cations.
6468. The method ofclaim 6460, wherein the one or more components comprise calcium.
6469. The method ofclaim 6460, wherein the one or more components comprise magnesium.
6470. The method of claim 6460, wherein the one or more components comprise a microorganism.
6471. The method ofclaim 6460, wherein the converted portion ofthe formation further comprises a pore size such that at least one ofthe one or more components is removed from the provided water.
6472. The method of claim 6460, wherein the converted portion ofthe formation adsorbs at least one ofthe one or more components in the provided water.
6473. The method of claim 6460, wherein the provided water comprises formation water.
6474. The method of claim 6460, wherein the in situ conversion process comprises pyrolysis.
6475. The method ofclaim 6460, wherein the in situ conversion process comprises synthesis gas generation.
6476. The method of claim 6460, wherein the in situ conversion process comprises solution mining.
6477. A method for sequestering carbon dioxide in a relatively low permeability foimation containing heavy hydrocarbons, comprising: providing carbon dioxide to a portion ofthe formation, wherein the portion has previously undergone an in situ conversion process; providing a fluid to the portion; allowing at least some ofthe provided carbon dioxide to contact the fluid in the portion; and precipitating carbonate compounds.
6478. The method of claim 6477, wherein providing a solution to the portion comprises allowing groundwater to flow into the portion.
6479. The method ofclaim 6477, wherein the solution comprises one or more dissolved ions.
6480. The method of claim 6477, wherein the solution comprises a solution obtained from a formation aquifer.
6481. The method of claim 6477, wherein the solution comprises a man-made indusfrial solution.
6482. The method of claim 6477, wherein the solution comprises agricultural run-off.
6483. The method of claim 6477, wherein the solution comprises seawater.
6484. The method ofclaim 6477, wherein the solution comprises a brine solution.
6485. The method ofclaim 6477, further comprising controlling a temperature within the portion.
6486. The method of claim 6477, further comprising confrolling a pressure within the portion.
6487. The method of claim 6477, further comprising removing at least some ofthe solution from the foimation.
6488. The method ofclaim 6477, further comprising removing at least some ofthe solution from the foπnation and recycling at least some ofthe removed solution into the formation.
6489. The method of claim 6477, further comprising providing a buffering compound to the solution.
6490. The method ofclaim 6477, further comprising: providing the solution to the formation; and allowing at least some ofthe solution to migrate through the formation to increase a contact time between the solution and the provided carbon dioxide.
6491. The method of claim 6477, wherein the solution is provided to the formation after carbon dioxide has been provided to the formation.
6492. The method of claim 6477, further comprising providing heat to the portion.
6493. The method of claim 6477, wherein providing carbon dioxide to a portion ofthe formation comprises providing carbon dioxide to a first location, wherein providing a solution to the portion comprises providing the solution to a second location, and wherein the ffrst location is downdip ofthe second location.
6494. The method ofclaim 6477, wherein allowing at least some ofthe provided carbon dioxide to contact the solution in the portion comprises allowing at least some ofthe carbon dioxide and at least some ofthe solution to migrate past each other.
6495. The method of claim 6477, wherein the solution is provided to the formation prior to providing the carbon dioxide, and further comprising providing at least some ofthe carbon dioxide to a location positioned proxhnate a lower surface ofthe portion such that some ofthe carbon dioxide may migrate up through the portion.
6496. The method of claim 6477, wherein the solution is provided to the formation prior to providing the carbon dioxide, and further comprising allowing at least some carbon dioxide to migrate through the portion.
6497. The method of claim 6477, further comprising: providing heat to the portion, wherein the portion comprises a temperature greater than about a boiling point ofthe solution; vaporizing at least some ofthe solution; producing a fluid from the formation.
6498. The method ofclaim 6477, further comprising decreasing leaching of metals from the formation into groundwater.
6499. A method of freathig a relatively low permeability formation containing heavy hydrocarbons, comprising: injecting a recovery fluid into a portion ofthe formation; allowing heat within the recovery fluid, and heat from one or more heat sources, to transfer to a selected section ofthe formation, wherein the selected section comprises hydrocarbons; mobilizing at least some ofthe hydrocarbons within the selected section; and
producing a mixture from the formation.
6500. The method ofclaim 6499, wherein the portion has been previously produced.
6501. The method ofclaim 6499, wherein the portion has previously undergone an in situ conversion process.
6502. The method of claim 6499, further comprising upgrading at least some hydrocarbons within the selected section to decrease a viscosity o the hydrocarbons.
6503. The method of claim 6499, wherein the produced mixture comprises hydrocarbons having an average API gravity greater than about 25°.
6504. The method of claim 6499, further comprising vaporizing at least some ofthe hydrocarbons within the selected section.
6505. The method ofclaim 6499, wherein the recovery fluid comprises water.
6506. The method ofclaim 6499, wherein the recovery fluid comprises hydrocarbons.
6507. The method ofclaim 6499, wherein the mixture comprises pyrolyzation fluids.
6508. The method of claim 6499, wherein the mixture comprises hydrocarbons.
6509. The method ofclaim 6499, wherein the mixture is produced from a production well and further comprising confrollmg a pressure such that a fluid pressure proximate to the production well is less than about a fluid pressure proximate to a location where the fluid is injected.
6510. The method of claim 6499, further comprising: monitoring a composition ofthe produced mixture; and controlling a fluid pressure in at least a portion ofthe foimation to confrol the composition ofthe produced mixture.
6511. The method of claim 6499, further comprising pyrolyzing at least some ofthe hydrocarbons within the selected section ofthe foπnation. 6512.
6513. The method of claim 6499, wherein the average temperature ofthe selected section is between about 275 °C to about 375 °C, and wherehi a fluid pressure ofthe recovery fluid is between about 60 bars to about 220 bars, and wherein the recovery fluid comprises steam.
6514. The method of claim 6499, further comprising controlling pressure within the selected section such that a fluid pressure within the selected section is at least about a hydrostatic pressure of a sunounding portion ofthe formation.
6515. The method of claim 6499, further comprising controlling pressure within the selected section such that a fluid pressure within the selected section is greater than about a hydrostatic pressure of a sunounding portion ofthe formation.
6516. The method ofclaim 6499, wherein a depth ofthe selected section is between about 300 m to about 400 m.
6517. The method ofclaim 6499, wherein the mixture comprises pyrolysis products.
6518. The method ofclaim 6499, further comprising vaporizing at least some ofthe hydrocarbons within the selected section and wherein the vaporized hydrocarbons comprise hydrocarbons having a carbon number greater than about 1 and a carbon number less than about 4.
6519. The method of claim 6499, further comprising allowing the injected recovery fluid to contact a substantial portion of a volume ofthe selected section.
6520. The method of claim 6499, wherein the recovery fluid comprises steam, and wherein the pressure ofthe injected steam is at least about 90 bars, and wherein the temperature ofthe injected steam is at least about 300 °C.
6521. The method of clahn 6499, further comprising upgrading at least a portion of the hydrocarbons within the selected section ofthe formation such that a viscosity ofthe portion ofthe hydrocarbons is decreased.
6522. The method of claim 6499, further comprising separating the recovery fluid from pyrolyzation fluid and distilled hydrocarbons in the foπnation, and further comprising producing the pyrolyzation fluid and distilled hydrocarbons.
6523. The method of claim 6499, wherein the ttansfer fluid and vaporized hydrocarbons are separated with membranes.
6524. The method of claim 6499, wherein the selected section comprises a ffrst selected section and a second selected section and further comprising: mobilizing at least some ofthe hydrocarbons within the selected first section ofthe formation; allowing at least some ofthe mobilized hydrocarbons to flow from the selected ffrst section ofthe foπnation to a selected second section ofthe foπnation, and wherein the selected second section comprises hydrocarbons; and
heating at least a portion ofthe foπnation using one ore more heat sources; pyrolyzing at least some ofthe hydrocarbons within the selected second section ofthe formation; and producing a mixttire from the foπnation.
6525. The method ofclaim 6499, wherein a residence thne ofthe recovery fluid in the formation is greater than about one month and less than about six months.
6526. The method of claim 6499, further comprising: allowing the recovery fluid to soak in the selected section ofthe foπnation for a selected time period; and producing at least a portion ofthe recovery fluid from the formation.
6527. A method of freating relatively low peπneability formation containing heavy hydrocarbons in situ, comprising: injecting a recovery fluid into the formation; providing heat from one or more heat sources to the formation; allowing the heat to fransfer from one or more ofthe heat sources to a selected section ofthe formation, wherein the selected section comprises hydrocarbons; mobilizing at least some ofthe hydrocarbons; and producing a mixture from the foimation, wherein the produced mixture comprises hydrocarbons having an average API gravity greater than about 25°.
6528. The method ofclaim 6527, wherein the heat provided from at least one ofthe one or more heat sources is fransfened to at least a portion ofthe foπnation substantially by conduction.
6529. The method of claim 6527, wherein the mixture is produced from the foimation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6530. The method ofclaim 6527, wherein at least one ofthe one or more ofthe heat sources comprises a heater.
6531. The method ofclaim 6527, further comprising pyrolyzing at least some ofthe hydrocarbons within selected section.
6532. The method ofclaim 6527, further comprising pyrolyzing at least some ofthe mobilized hydrocarbons.
6533. The method of claim 6527, wherein the recovery fluid comprises water.
6534. The method of claim 6527, wherein the recovery fluid comprises hydrocarbons.
6535. The method of claim 6527, wherein the mixture comprises pyrolyzation fluids.
6536. The method o claim 6527, wherein the mixture comprises steam.
6537. The method of clahn 6527, wherein a pressure is controlled such that a fluid pressure proximate to one or more ofthe heat sources is greater than a fluid pressure proximate to a location where the fluid is produced
6538. The method ofclaim 6527, wherein the one or more heat sources comprise at least two heat sources, and wherein supeφosition of heat from at least the two heat sources pyrolyzes at least some hydrocarbons within the selected section ofthe formation.
6539. The method ofclaim 6527, wherein the heat is provided such that an average temperature in the selected section ranges from approximately about 270 °C to about 375 °C.
6540. The method ofclaim 6527, further comprising: monitoring a composition ofthe produced mixture; and controlling a pressure in at least a portion ofthe foimation to control the composition ofthe produced mixture.
6541. The method of claim 6540, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.
6542. The method of claim 6540, wherein the pressure is controlled such that pressure proximate to one or more ofthe heat sources is greater than a pressure proxhnate to a location where the mixture is produced.
6543. The method of clahn 6527, wherein a residence time ofthe recovery fluid in the formation is less than about one month to greater than about six months.
6544. The method ofclaim 6527, further comprising: allowing the recovery fluid to soak in the selected section ofthe formation for a selected time period; and producing at least a portion ofthe recovery fluid from the foπnation.
6545. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: injecting a recovery fluid into a formation; allowing the recovery fluid to migrate through at least a portion ofthe formation, wherein a size of a selected section increases as a recovery fluid front migrates through an untreated portion ofthe formation, and wherein the selected section is a portion ofthe foπnation treated by the recovery fluid; allowing heat from the recovery fluid to fransfer heat to the selected section, wherein the heat from the recovery fluid, and heat from one or more heat sources, pyrolyzes at least some ofthe hydrocarbons within the selected section of the formation;
allowing the heat from the recovery fluid or one or more heat sources to mobilize at least some ofthe hydrocarbons at the recovery fluid front; allowing the heat from the recovery fluid, and heat from one or more heat sources, to pyrolyze at least a portion ofthe hydrocarbons in the mobilized fluid; and producing a mixture from the formation.
6546. The method of clahn 6545, wherein the formation comprises a heavy relatively low permeability formation containing heavy hydrocarbons.
6547. The method of claim 6545, wherein one or more heat sources are heaters.
6548. The method of claim 6545, wherein the mixture is produced as a mixture of vapors.
6549. The method ofclaim 6545, wherein an average temperature o the selected section is about 300 °C, and wherehi the recovery fluid pressure is about 90 bars.
6550. The method of clahn 6545, wherein the mobilized hydrocarbons flow substantially parallel to the recovery fluid front.
6551. The method of claim 6545, wherein the mixture is produced from an upper portion ofthe fonnation.
6552. The method ofclaim 6545, wherein a portion ofthe recovery fluid condenses and migrates due to gravity to a lower portion ofthe selected section, and further comprising producing a portion ofthe condensed recovery fluid.
6553. The method of claim 6545, wherein the pyrolyzed fluid migrates to an upper portion ofthe formation.
6554. The method of claim 6545, wherein the mixture comprises pyrolyzation fluids.
6555. The method ofclaim 6545, wherein the mixture comprises recovery fluid.
6556. The method ofclaim 6545, wherein the recovery fluid comprises steam.
6557. The method ofclaim 6545, wherein the recovery fluid is injected through one or more injection wells.
6558. The method of clahn 6557, wherein the one or more injection wells are located substantially horizontally in the fonnation.
6559. The method of clahn 6557, wherehi the one or more injection wells are located substantially vertically in the foπnation.
6560. The method of clahn 6545, wherein the mixture is produced through one or more production wells.
6561. The method of claim 6560, wherein the one or more production wells are located substantially horizontally in the foimation.
6562. The method of claim 6545, wherein the mixture is produced through a heat source wellbore.
6563. The method of claim 6545, wherein the produced mixture comprises hydrocarbons having an average API gravity at least about 25°.
6564. The method of claim 6545, wherein at least about 20% ofthe hydrocarbons in the selected first section and the selected second section are pyrolyzed.
6565. The method ofclaim 6545, further comprising providing heat from one or more heat sources to at least one portion ofthe formation.
6566. The method of claim 6545, wherein the heat from the one or more heat sources vaporizes water injected into the formation.
6567. The method of clahn 6545, wherein the heat from the one or more heat sources heats recovery fluid in the foimation, wherein the recovery fluid comprises steam.
6568. The method ofclaim 6545, wherein the one or more heat sources comprise electrical heaters.
6569. The method ofclaim 6545, wherein the one or more heat sources comprise flame disfributed combustors.
6570. The method ofclaim 6545, wherein the one or more heat sources comprise natural disfributed combustors.
6571. The method of claim 6545, further comprishig separating recovery fluid from pyrolyzation fluids in the fonnation.
6572. The method of claim 6545, further comprising producing liquid hydrocarbons from the formation, and ftirther comprising reinjecting the produced liquid hydrocarbons into the formation.
6573. The method of claim 6545, further comprising producing a liquid mixture from the formation, wherein the produced liquid mixture comprises substantially of condensed recovery fluid.
6574. The method of claim 6545, further comprising separating condensed recovery fluid from liquid hydrocarbons in the formation, and further comprising producing the condensed recovery fluid from the formation.
6575. The method ofclaim 6545, wherein the recovery fluid is injected into regions of relatively high water saturation.
6576. The method ofclaim 6545, wherein injected recovery fluid contacts a substantial portion of a volume of the selected section.
6577. The method of claim 6545, wherein the recovery fluid comprises steam, and wherein the pressure ofthe injected steam is at least about 90 bars, and wherehi the temperature of the injected steam is at least about 300 °C.
6578. The method ofclaim 6545, wherein at least a portion of sulfur is retained in the formation.
6579. The method of claim 6545, wherein the heat from recovery fluid partially upgrades at least a portion ofthe hydrocarbons within the selected section ofthe formation, and wherein the partial upgrading reduces the viscosity ofthe portion ofthe hydrocarbons.
6580. The method ofclaim 6545, further comprising separating the recovery fluid from pyrolyzation fluid and distilled hydrocarbons in the formation, and further comprising producing the pyrolyzation fluid and distilled hydrocarbons.
6581. The method of claim 6545, wherein the recovery fluid and vaporized hydrocarbons are separated with membranes.
6582. The method ofclaim 6545, wherein a residence time ofthe recovery fluid in the formation is less than about one month to greater than about six months.
6583. The method of claim 6545, further comprising: allowing the heat fransfer fluid to soak in the selected section ofthe formation for a selected time period; and producing at least a portion ofthe heat ttansfer fluid from the foπnation.
6584. A method of shutting-in an in situ treatment process in a relatively low permeability foimation containing heavy hydrocarbons, comprising: terminating heating from one or more heat sources providing heat to a portion ofthe formation; monitoring a pressure in at least a portion ofthe formation;
conttoUing the pressure in the portion ofthe formation such that the pressure is maintained approxhnately below a fracturing or breakthrough pressure ofthe formation.
6585. The method ofclaim 6584, wherein monitoring the pressure in the formation comprises detecting fractures ■ with passive acoustic monitoring.
6586. The method ofclaim 6584, wherein confrolling the pressure in the portion ofthe formation comprises: producing hydrocarbon vapor from the formation when the pressure is greater than approximately the fracturing or breakthrough pressure of the formation; and allowing produced hydrocarbon vapor to oxidize at a surface ofthe formation.
6587. The method ofclaim 6584, wherein controlling the pressure in the portion ofthe foπnation comprises: producing hydrocarbon vapor from the formation when the pressure is greater than approximately the fracturing or breakthrough pressure ofthe formation; and storing at least a portion of the produced hydrocarbon vapor.
6588. A method of shutting-in an in situ treatment process in a relatively low permeability foimation containing heavy hydrocarbons, comprising: terminating heating from one or more heat sources providing heat to a portion ofthe formation; producing hydrocarbon vapor from the foimation; and injecting at least a portion ofthe produced hydrocarbon vapor into a portion of a storage formation.
6589. The method ofclaim 6588, wherein the storage formation comprises a spent formation.
6590. The method of claim 6589, wherein an average temperature ofthe portion of the spent formation is less than about 100°C.
6591. The method of claim 6589, wherein a substantial portion of condensable compounds in the injected hydrocarbon vapor condense in the spent formation.
6592. The method of claim 6588, wherein the storage formation comprises a relatively high temperature foimation, and further comprising converting a substantial portion of injected hydrocarbons into coke and molecular hydrogen.
6593. The method ofclaim 6592, wherein the average temperature ofthe portion ofthe relatively high temperature foimation is greater than about 300°C.
6594. The method of claim 6592, further comprising: producing at least a portion ofthe H2 from the relatively high temperature foπnation; and
allowing the produced molecular hydrogen to oxidize at a surface ofthe relatively high temperature formation.
6595. The method of claim 6588, wherein the storage formation comprises a depleted foπnation.
6596. The method of claim 6595, wherein the depleted formation comprises an oil field.
6597. The method of claim 6595, wherein the depleted foπnation comprises a gas field.
6598. The method of claim 6595, wherein the depleted foπnation comprises a water zone comprising seal and trap integrity.
6599. A method of producing a soluble compound from a soluble compound containing formation, comprising: providing heat from one or more heat sources to at least a portion of a hydrocarbon containing layer; producing a mixture comprising hydrocarbons from the fonnation; using heat from the formation, heat from the mixture produced from the formation, or a component from the mixture produced from the formation to adjust a quality of a ffrst fluid; providing the first fluid to a soluble compound containing formation; and producing a second fluid comprishig a soluble compound from the soluble compound containing foimation.
6600. The method ofclaim 6599, further comprising pyrolyzing at least some hydrocarbons in the hydrocarbon containing layer.
6601. The method of claim 6599, further comprising dissolving the soluble compound in the soluble compound containing formation.
6602. The method o claim 6599, wherein the soluble compound comprises a phosphate.
6603. The method of claim 6599, wherein the soluble compound comprises alumina.
6604. The method of claim 6599, wherein the soluble compound comprises a metal.
6605. The method of claim 6599, wherein the soluble compound comprises a carbonate.
6606. The method ofclaim 6599, further comprising separating at least a portion ofthe soluble compound from the second fluid.
6607. The method ofclaim 6599, further comprising separating at least a portion ofthe soluble compound from the second fluid, and then recycling a portion ofthe second fluid into the soluble compound containing formation.
6608. The method ofclaim 6599, wherein heat is provided from the heated formation, or from the mixture produced from the formation, in the form of hot water or steam.
6609. The method ofclaim 6599, wherein the quality ofthe first fluid that is adjusted is pH.
6610. The method ofclaim 6599, wherein the quality ofthe first fluid that is adjusted is temperature.
6611. The method of clahn 6599, further comprising adding a dissolving compound to the first fluid that facilitates dissolution ofthe soluble compound in the soluble containing formation.
6612. The method ofclaim 6599, wherein C02 produced from the hydrocarbon containing layer is used to adjust acidity ofthe solution.
6613. The method of claim 6599, wherein the soluble compound containing foimation is at a different depth than the portion of the hydrocarbon containing layer.
6614. The method ofclaim 6599, wherein heat from the portion ofthe hydrocarbon containing layer migrates and heats at least a portion ofthe soluble compound containing formation.
6615. The method of claim 6599, wherein the soluble compound containing formation is at a different location than the portion ofthe hydrocarbon containing layer.
6616. The method ofclaim 6599, further comprising using openings for providing the heat sources, and further comprising using at least a portion of these openings to provide the first fluid to the soluble compound containing formation.
6617. The method of claim 6599, further comprising providing the solution to the soluble compound containing foπnation in one or more openings that were previously used to (a) provide heat to the hydrocarbon containing layer, or (b) produce the mixture from the hydrocarbon containing layer.
6618. The method of claim 6599, further comprising providing heat to the hydrocarbon containing layer, or producing the mixture from the hydrocarbon containing layer, using one or more openings that were previously used to provide a solution to a soluble compound containing formation.
6619. The method ofclaim 6599, further comprising: separating at least a portion ofthe soluble compound from the second fluid; providing heat to at least the portion ofthe soluble compound; and wherein the provided heat is generated in part using one or more products of an in situ conversion process.
6620. The method of claim 6599, further comprising producing the second fluid when a partial pressure of hydrogen in the portion ofthe hydrocarbon containing layer is at least about 0.5 bars absolute.
6621. The method of claim 6599, wherein the heat provided from at least one heat source is fransfened to at least a part ofthe hydrocarbon containing layer substantially by conduction.
6622. The method of claim 6599, wherein one or more ofthe heat sources comprise heaters.
6623. The method of claim 6599, wherein the soluble compound containing fonnation comprises nahcolite.
6624. The method ofclaim 6599, wherein greater than about 10 % by weight ofthe soluble compound , containing formation comprises nahcolite.
6625. The method ofclaim 6599, wherein the soluble compound containing formation comprises dawsonite.
6626. The method of claim 6599, wherein greater than about 2 % by weight ofthe soluble compound containing formation comprises dawsonite.
6627. The method of claim 6599, wherein the first fluid comprises steam.
6628. The method ofclaim 6599, wherein the ffrst fluid comprises steam, and further comprising providing heat to the soluble compound containing formation by injecting the steam into the formation.
6629. The method of claim 6599, wherein the soluble compound containing foπnation is heated and then the first fluid is provided to the formation.
6630. A method of freating a relatively low peπneability formation containing heavy hydrocarbons in situ, comprising: providing heat to at least a portion ofthe formation; allowing the heat to fransfer from at least the portion to a selected section ofthe formation such that dissociation of carbonate minerals is inhibited; injecting a first fluid into the selected section; producing a second fluid from the formation; and conducting an in situ conversion process in the selected section.
6631. The method ofclaim 6630, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the fonnation is at least about 0.5 bars absolute.
6632. The method ofclaim 6630, wherein the heat is provided from at least one heat source, and wherein the heat is transfened to at least the portion ofthe foπnation substantially by conduction.
6633. The method of clahn 6630, wherein the in situ conversion process comprises: providing additional heat to a least a portion ofthe formation; pyrolyzing at least some hydrocarbons in the portion; and producing a mixture from the formation.
6634. The method ofclaim 6630, wherein the selected section comprises nahcolite.
6635. The method of claim 6630, wherein the selected section comprises dawsonite.
6636. The method ofclaim 6630, wherein the selected section comprises frona.
6637. The method ofclaim 6630, wherein the selected section comprises gaylussite.
6638. The method ofclaim 6630, wherein the selected section comprises carbonates.
6639. The method of claim 6630, wherein the selected section comprises carbonate phosphates.
6640. The method ofclaim 6630, wherein the selected section comprises carbonate chlorides.
6641 , The method ofclaim 6630, wherein the selected section comprises silicates.
6642. The method ofclaim 6630, wherein the selected section comprises borosilicates.
6643. The method of clahn 6630, wherein the selected section comprises halides.
6644. The method of claim 6630, wherein the first fluid comprises a pH greater than about 7.
6645. The method ofclaim 6630, wherein the first fluid comprises a temperature less than about 110 °C.
6646. The method ofclaim 6630, wherein the portion has previously undergone an in situ conversion process prior to the injection ofthe first fluid.
6647. The method of clahn 6630, wherein the second fluid comprises hydrocarbons.
6648. The method of claim 6630, wherein the second fluid comprises hydrocarbons, and further comprising: fragmenting at least some ofthe portion prior to providing the ffrst fluid; generating hydrocarbons; and providing at least some ofthe second fluid to a surface freatment unit, wherein the second fluid comprises at least some ofthe generated hydrocarbons.
6649. The method ofclaim 6630, further comprising removing mass from the selected section in the second fluid.
6650. The method of claim 6630, further comprising removing mass from the selected section in the second fluid such that a permeability ofthe selected section increases.
6651. The method of claim 6630, further comprising removing mass from the selected section in the second fluid and decreasing a heat fransfer time in the selected section.
6652. The method ofclaim 6630, further comprising controlling the heat such that the selected section has a temperature of above about 120 °C.
6653. The method of clahn 6630, wherein the selected section comprises nahcolite, and further comprising controlling the heat such that the selected section has a temperature less than about a dissociation temperature of nahcolite.
6654. The method of claim 6630, wherein the second fluid comprises soda ash, and further comprising removing at least a portion ofthe soda ash from the second fluid as sodium carbonate.
6655. The method of claim 6630, wherein the in situ conversion process comprises pyrolyzing hydrocarbon containing material in the selected section.
6656. The method of claim 6630, wherein the second fluid comprises nahcolite, and further comprising: separating at least a portion ofthe nahcolite from the second fluid; providing heat to at least some ofthe separated nahcolite to form a sodium carbonate solution; providing at least some ofthe sodium carbonate solution to at least the portion ofthe foimation; and producing a third fluid comprising alumina from the formation.
6657. The method of claim 6630, further comprising providing a banier to at least the portion ofthe formation to inhibit migration of fluids into or out of the portion.
6658. The method of claim 6630, further comprising controlling the heat such that a temperature within the selected section ofthe portion is less than about 100 °C.
6659. The method of claim 6630, further comprising: providing additional heat from the one or more heat sources to at least the portion ofthe formation; allowing the additional heat to transfer from at least the portion to the selected section ofthe fonnation; pyrolyzing at least some hydrocarbons within the selected section ofthe formation; producing a mixture from the formation;
reducing a temperature ofthe selected section ofthe formation injecting a thfrd fluid into the selected section; and producing a fourth fluid from the formation.
6660. The method of claim 6659, wherein the thfrd fluid comprises water.
6661. The method of claim 6659, wherein the thfrd fluid comprises steam.
6662. The method of claim 6659, wherein the fourth fluid comprises a metal.
6663. The method of claim 6659, wherein the fourth fluid comprises a mineral.
6664. The method of clahn 6659, wherein the fourth fluid comprises aluminum.
6665. The method of claim 6659, wherein the fourth fluid comprises a metal, and further comprising producing the metal from the second fluid.
6666. The method of claim 6659, further comprising producing a non-hydrocarbon material from the fourth fluid.
6667. The method of claim 6630, wherein the first fluid comprises steam.
6668. The method ofclaim 6630, wherein the second fluid comprises a metal.
6669. The method of claim 6630, wherein the second fluid comprises a mineral.
6670. The method of claim 6630, wherein the second fluid comprises aluminum.
6671. The method ofclaim 6630, wherein the second fluid comprises a metal, and further comprising separating the metal from the second fluid.
6672. The method of claim 6630, further comprising producing a non-hydrocarbon material from the second fluid.
6673. The method ofclaim 6630, wherein greater than about 10 % by weight ofthe selected section comprises nahcolite.
6674. The method of claim 6630, wherein greater than about 2 % by weight ofthe selected section comprises dawsonite.
6675. The method of claim 6630, wherein the provided heat comprises waste heat from another portion ofthe formation.
6676. The method of clahn 6630, wherein the first fluid comprises steam, and further comprising providing heat to the foπnation by injecting the steam into the formation.
6677. The method of claim 6630, further comprising providing heat to the formation by injecting the first fluid into the formation.
6678. The method ofclaim 6630, further comprising providing heat to the formation by injecting the ffrst fluid into the formation, wherein the first fluid is at a temperature above about 90° C.
6679. The method of claim 6630, further comprising controlling a temperature ofthe selected section while injecting the first fluid, wherein the temperature is less than about a temperature at which nahcolite will dissociate.
6680. The method of claim 6630, wherein a temperature within the selected section is less than about 90 °C prior to injecting the first fluid to the formation.
6681. The method of claim 6630, further comprising providing a banier substantially sunounding the selected section such that the banier inhibits the flow of water into the foπnation.
6682. A method of freating a relatively low peπneability foπnation containing heavy hydrocarbons in situ, comprising: injecting a first fluid into the selected section; producing a second fluid from the formation; providing heat from one or more heat sources to at least a portion ofthe formation, wherein the heat is provided after production ofthe second fluid has begun; allowing the heat to fransfer from at least a portion ofthe foimation; pyrolyzing at least some hydrocarbons within the selected section; and producing a mixture from the formation.
6683. The method of claim 6682, wherein the selected section comprises nahcolite.
6684. The method ofclaim 6682, wherein the selected section comprises dawsonite.
6685. The method ofclaim 6682, wherein the selected section comprises trona.
6686. The method ofclaim 6682, wherein the selected section comprises gaylussite.
6687. The method ofclaim 6682, wherein the selected section comprises carbonates.
6688. The method ofclaim 6682, wherein the selected section comprises carbonate phosphates.
6689. The method ofclaim 6682, wherein the selected section comprises carbonate chlorides.
6690. The method ofclaim 6682, wherein the selected section comprises silicates.
6691. The method of claim 6682, wherein the selected section comprises borosilicates.
6692. The method ofclaim 6682, wherein the selected section comprises halides.
6693. The method of claim 6682, wherein the first fluid comprises a pH greater than about 7.
6694. The method ofclaim 6682, wherein the first fluid comprises a temperature less than about 110 °C.
6695. The method ofclaim 6682, wherein the second fluid comprises hydrocarbons.
6696. The method ofclaim 6682, wherein the second fluid comprises hydrocarbons, and further comprising: fragmenting at least some ofthe portion prior to providing the first fluid; generating hydrocarbons; and providing at least some ofthe second fluid to a surface freatment unit, wherein the second fluid comprises at least some ofthe generated hydrocarbons.
6697. The method ofclaim 6682, further comprising removing mass from the selected section in the second fluid.
6698. The method ofclaim 6682, further comprising removing mass from the selected section in the second fluid such that a permeability ofthe selected section increases.
6699. The method ofclaim 6682, further comprising removing mass from the selected section in the second fluid and decreasing a heat transfer time in the selected section.
6700. The method ofclaim 6682, ftirther comprising controlling the heat such that the selected section has a temperature of above about 270 °C.
6701. The method ofclaim 6682, wherein the second fluid comprises soda ash, and further comprising removing at least a portion ofthe soda ash from the second fluid as sodium carbonate.
6702. The method ofclaim 6682, wherein the second fluid comprises nahcolite, and further comprishig: separating at least a portion ofthe nahcolite from the second fluid; providing heat to at least some ofthe separated nahcolite to foπn a sodium carbonate solution; providing at least some ofthe sodium carbonate solution to at least the portion ofthe formation; and producing a thfrd fluid comprising alumina from the formation.
6703. The method of claim 6682, further comprising providing a banier to at least the portion ofthe formation to inhibit migration of fluids into or out ofthe portion.
6704. The method ofclaim 6682, wherein the first fluid comprises steam.
6705. The method ofclaim 6682, wherein the second fluid comprises a metal.
6706. The method ofclaim 6682, wherein the second fluid comprises a mineral.
6707. The method of claim 6682, wherein the second fluid comprises aluminum.
6708. The method of claim 6682, wherein the second fluid comprises a metal, and further comprising separating the metal from the second fluid.
6709. The method of claim 6682, further comprising producing a non-hydrocarbon material from the second fluid.
6710. The method ofclaim 6682, wherein greater than about 10 % by weight ofthe selected section comprises nahcolite.
6711. The method ofclaim 6682, wherein greater than about 2 % by weight ofthe selected section comprises dawsonite.
6712. The method ofclaim 6682, wherein at least some ofthe provided heat comprises waste heat from another portion ofthe formation.
6713. The method of claim 6682, wherein the ffrst fluid comprises steam, and further comprising providing heat to the fonnation by injecting the steam into the formation.
6714. The method of claim 6682, further comprising providing heat to the formation by injecting the first fluid into the foπnation.
6715. The method of claim 6682, further comprising providing heat to the formation by injecting the first fluid into the formation, wherein the first fluid is at a temperature above about 90° C.
6716. The method of clahn 6682, further comprising confrolling a temperature ofthe selected section while injecting the first fluid, wherein the temperature is less than about a temperature at which nahcolite will dissociate.
6717. The method ofclaim 6682, fuither comprising providing a banier substantiaUy suirounding the selected section such that the banier inhibits the flow of water into the fonnation.
6718. The method ofclaim 6682, wherein the mixture is produced from the foπnation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.
6719. The method of claim 6682, wherehi the heat provided from at least one heat source is fransfened to at least a portion ofthe formation substantially by conduction.
6720. The method of claim 6682, wherein the one or more ofthe heat sources comprise heaters.
6721. A method of solution mining alumina from an in situ relatively low permeability foπnation containing heavy hydrocarbons, comprising: providing heat from one or more heat sources to a least a portion ofthe formation; pyrolyzing at least some hydrocarbons in the portion; and producing a mixture from the formation providing a brine solution to a portion ofthe formation; and producing a mixture comprising alumina from the formation.
6722. The method ofclaim 6721, wherein the selected section comprises dawsonite.
6723. The method of claim 6721 , further comprising: separathig at least a portion ofthe alumina from the mixture; and providing heat to at least the portion ofthe alumina to generate aluminum.
6724. The method of claim 6721 , further comprising: separating at least a portion ofthe alumina from the mixture; providing heat to at least the portion ofthe alumina to generate aluminum; and wherein the provided heat is generated in part using one or more products of an in situ conversion process.
6725. The method of claim 6721 , further comprising producing the mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.
6726. The method ofclaim 6721, wherein the heat provided from at least one heat source is fransfened to at least a portion ofthe formation substantially by conduction.
6727. The method ofclaim 6721, wherein one or more ofthe heat sources comprise heaters.
6728. A method of freating a relatively low penneability formation containing heavy hydrocarbons in situ, comprising: allowing a temperature of a portion ofthe formation to decrease, wherein the portion has previously undergone an in situ conversion process; injecting a first fluid into the selected section; and producing a second fluid from the formation.
6729. The method of claim 6728, wherein the in situ conversion process comprises: providing heat to a least a portion ofthe foπnation; pyrolyzing at least some hydrocarbons in the portion; and producing a mixture from the formation.
6730. The method ofclaim 6728, wherein the ffrst fluid comprises water.
6731. The method ofclaim 6728, wherein the second fluid comprises a metal.
6732. The method ofclaim 6728, wherehi the second fluid comprises a mineral.
6733. The method of claim 6728, wherein the second fluid comprises aluminum.
6734. The method of claim 6728, wherein the second fluid comprises a metal, and further comprising producing the metal from the second fluid.
6735. The method ofclaim 6728, further comprising producing a non-hydrocarbon material from the second fluid.
6736. The method ofclaim 6728, wherein the selected section comprises nahcolite.
6737. The method ofclaim 6728, wherein greater than about 10 % by weight ofthe selected section comprises nahcolite.
6738. The method ofclaim 6728, wherein the selected section comprises dawsonite.
6739. The method ofclaim 6728, wherein greater than about 2 % by weight ofthe selected section comprises dawsonite.
6740. The method of claim 6728, wherein the provided heat comprises waste heat from another portion ofthe foπnation.
6741. The method of claim 6728, wherein the first fluid comprises steam.
6742. The method of claim 6728, wherein the first fluid comprises steam, and further comprising providing heat to the formation by injecting the steam into the foπnation.
6743. The method of clahn 6728, further comprising providing heat to the foπnation by injecting the first fluid into the formation.
6744. The method of claim 6728, further comprising providing heat to the formation by injecting the first fluid into the formation, wherein the first fluid is at a temperature above about 90° C.
6745. The method ofclaim 6728, wherein the reduced temperature ofthe selected section is less than about 90 °C.
6746. The method ofclaim 6728, wherein an average richness of at least the portion ofthe selected section is greater than about 0.10 liters per kilogram.
6747. A method for treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to at least a portion of a relatively low permeability formation containing heavy hydrocarbons; allowing heat to fransfer from one or more heat sources to a first selected section of a relatively low permeability formation containing heavy hydrocarbons such that the heat reduces the viscosity of at least some hydrocarbons within the first selected section; producing a first mixture from the first selected section; allowing heat to transfer from one or more heat sources to a second selected section of a relatively low permeability formation containing heavy hydrocarbons such that the heat pyrolyzes at least some hydrocarbons within the second selected section; producing a second mixture from the second selected section; and blending at least a portion ofthe first mixture with at least a portion ofthe second mixture to produce a thfrd mixture comprising a selected property.
6748. The method ofclaim 6747, wherein the selected property ofthe thfrd mixture comprises an API gravity.
6749. The method ofclaim 6747, wherein the selected property ofthe thfrd mixture comprises an API gravity of at least about 10°.
6750. The method of claim 6747, wherein the selected property ofthe thfrd mixture comprises a selected viscosity.
6751. The method of claim 6747, wherein the selected property of the thfrd mixture comprises a viscosity less than about 7500 cs.
6752. The method ofclaim 6747, wherein the selected property ofthe thfrd mixture comprises a density.
6753. The method ofclaim 6747, wherein the selected property ofthe third mixture comprises a density less than about 1 g cm3.
6754. The method of claim 6747, wherein the selected property ofthe thfrd mixture comprises an asphaltene to saturated hydrocarbon ratio of less than about 1.
6755. The method ofclaim 6747, wherein the selected property ofthe thfrd mixture comprises an aromatic hydrocarbon to saturated hydrocarbon ratio of less than about 4.
6756. The method of clahn 6747, wherein asphaltenes are substantially stable in the third mixture at ambient temperature.
6757. The method of claim 6747, wherein the third mixture is transportable.
6758. The method of claim 6747, wherein the thfrd mixture is transportable through a pipeline.
6759. The method ofclaim 6747, wherein the first mixture comprises an API gravity less than about 15°.
6760. The method of clahn 6747, wherein the second mixture comprises an API gravity greater than about 25°.
6761. The method of claim 6747, wherein the second mixture comprises an acid number less than about 1.
6762. The method ofclaim 6747, further comprising selecting a ratio ofthe first mixture to the second mixture such that at least about 50% by weight ofthe initial mass of hydrocarbons in a selected portion ofthe formation is produced.
6763. The method of claim 6747, wherein the third mixture comprises less than about 50 % by weight ofthe second mixture.
6764. The method of claim 6747, wherein the first selected section comprises a depth of at least about 500 m below the surface of a relatively low permeability foπnation containing heavy hydrocarbons.
6765. The method of claim 6747, wherein the second selected section comprises a depth less than about 500 m below the surface of a relatively low permeability formation containing heavy hydrocarbons.
6766. The method ofclaim 6747, wherein the ffrst selected section and the second selected section are located in different relatively low permeability fonnations containing heavy hydrocarbons.
6767. The method ofclaim 6747, wherein the ffrst selected section and the second selected section are located in different relatively low permeability formations containing heavy hydrocarbons, and wherein the different relatively low permeability foπnation containing heavy hydrocarbons are vertically displaced.
6768. The method ofclaim 6747, wherein the ffrst selected section and the second selected section are vertically displaced within a single relatively low permeability foπnation containing heavy hydrocarbons.
6769. The method of claim 6747, wherein the ffrst selected section and the second selected section are substantially adjacent within a single relatively low permeability foπnation containing heavy hydrocarbons.
6770. The method ofclaim 6747, wherein blending comprises injecting at least a portion ofthe second mixture into the first selected section such that the second mixture blends with at least a portion ofthe first mixture to produce the thfrd mixttire in the first selected section.
6771. The method ofclaim 6747, wherein blending comprises injecting at least a portion ofthe second mixture into a production well in the first selected section such that the second mixture blends with at least a portion ofthe first mixture to produce the third mixture in the production well.
6772. The method ofclaim 6747, further comprising producing a mixture when a partial pressure ofhydrogen in the formation is at least about 0.5 bars absolute.
6773. The method ofclaim 6747, wherein the heat provided from at least one heat source is transfened to at least a portion ofthe formation substantially by conduction.
6774. The method ofclaim 6747, wherein one or more ofthe heat sources comprise heaters.
The method ofclaim 6747, wherein a ratio of energy output ofthe ffrst or the second produced mixture to energy input into the formation is at least about 5.
6775. A method for freating a relatively low permeability foπnation containing heavy hydrocarbons in situ to produce a blending agent, comprising: providing heat from one or more heat sources to at least a portion ofthe relatively low permeability formation containing heavy hydrocarbons; allowing the heat to fransfer from the one or more heat sources to a selected section ofthe formation such that the heat pyrolyzes at least some hydrocarbons within the selected section; producing a blending agent from the selected section; and wherein at least a portion ofthe blending agent is adapted to blend with a liquid to produce a mixture with a selected property.
6776. The method of claim 6775, wherein the liquid comprises at least some heavy hydrocarbons.
6777. The method ofclaim 6775, wherein the liquid comprises an API gravity below about 15°.
6778. The method of claim 6775, wherein the liquid is viscous, and wherein a mixture produced by blending at least a portion ofthe blending agent with the liquid is less viscous than the liquid.
6779. The method of claim 6775, wherein the selected property ofthe mixture comprises an API gravity.
6780. The method ofclaim 6775, wherein the selected property ofthe mixture comprises an API gravity of at least about 10°.
6781. The method ofclaim 6775, wherein the selected property ofthe mixture comprises a selected viscosity.
6782. The method ofclaim 6775, wherein the selected property ofthe mixture comprises a viscosity less than about 7500 cs.
6783. The method of claim 6775, wherein the selected property of the mixture comprises a density.
6784. The method of claim 6775, wherein the selected property ofthe mixture comprises a density less than about 1 g/cm3.
6785. The method ofclaim 6775, wherein the selected property ofthe mixture comprises an asphaltene to saturated hydrocarbon ratio of less than about 1.
6786. The method of claim 6775, wherein the selected property ofthe mixture comprises an aromatic hydrocarbon to saturated hydrocarbon ratio of less than about 4.
6787 '. The method ofclaim 6775, wherein asphaltenes are substantiaUy stable in the mixture at ambient temperature.
6788. The method of claim 6775, wherein the mixture is transportable.
6789. The method of claim 6775, wherein the mixture is transportable through a pipeline.
6790. The method of claim 6775, wherein the liquid has a viscosity sufficiently high to inhibit economical transport ofthe liquid over 100 km via a pipeline but the mixture has a reduced viscosity that allows economical fransport of the mixture over 100 km via a pipeline.
6791. The method of claim 6775, further comprising producing the liquid from a second section of a relatively low permeability foimation containing heavy hydrocarbons and blending the liquid with the blending agent to produce the mixture.
6792. The method ofclaim 6775, further comprising producing the liquid from a second section of a relatively low permeability formation containing heavy hydrocarbons and blending the liquid with the blending agent to produce the mixture, wherein the mixture comprises less than about 50 % by weight ofthe blending agent.
6793. The method ofclaim 6775, further comprising injecting the blendhig agent into a second section of a relatively low permeability foimation containing heavy hydrocarbons such that the blending agent blends with the liquid in the second section to produce the mixture.
6794. The method of claim 6775, further comprising injecting the blending agent into a production well in a second section of a relatively low permeability formation containing heavy hydrocarbons such that the blending agent blends with the liquid in the production well to produce the mixture.
6795. The method ofclaim 6775, further comprising producing the blending agent when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.
6796. The method of claim 6775, wherein the heat provided from at least one heat source is transfened to at least a portion ofthe foπnation substantially by conduction.
6797. The method ofclaim 6775, wherein one or more ofthe heat sources comprise heaters.
6798. The method of claim 6775, wherein a ratio of energy output ofthe blending agent to energy input into the foπnation is at least about 5.
6799. The method ofclaim 6775, wherein the blending agent comprises an acid number less than about 1.
6800. A blending agent produced by a method, comprising: providing heat from one or more heat sources to at least a portion of a relatively low permeability formation containing heavy hydrocarbons; allowing the heat to fransfer from the one or more heat sources to a selected section ofthe formation such that the heat pyrolyzes at least some hydrocarbons within the selected section; and producing the blending agent from the selected section; wherein at least a portion ofthe blending agent is adapted to blend with a liquid to produce a mixture with a selected property. 6801. The blending agent ofclaim 6800, wherein the blending agent comprises an API gravity of at least about 20°.
6802. The blending agent ofclaim 6800, wherein the blendhig agent comprises an acid number less than about 1.
6803. The blending agent ofclaim 6800, wherein the blending agent comprises an asphaltene weight percentage less than about 0.5 % .
6804. The blending agent ofclaim 6800, wherein the blending agent comprises a combined nifrogen, oxygen, and sulfur weight percentage less than about 5 %.
6805. The blending agent ofclaim 6800, wherein asphaltenes are substantially stable in the mixttire at ambient temperature.
6806. The blending agent ofclaim 6800, wherein the method further comprises producing the blending agent when a partial pressure ofhydrogen in the foimation is at least about 0.5 bars absolute.
6807. The blending agent ofclaim 6800, wherein the method further comprises the heat provided from at least one heat source fransfening to at least a portion ofthe foimation substantially by conduction.
6808. The blending agent ofclaim 6800, wherein the method further comprises one or more ofthe heat sources comprising heaters.
6809. The blending agent ofclaim 6800, wherein the method further comprises a ratio of energy output ofthe blending agent to energy input into the formation being at least about 5.
6810. A method for freating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: producing a first mixture from a first selected section of a relatively low peπneability formation containing heavy hydrocarbons, wherein the first mixture comprises heavy hydrocarbons;
providing heat from one or more heat sources to a second selected section ofthe relatively low permeability formation containing heavy hydrocarbons such that the heat pyrolyzes at least some hydrocarbons within the second selected section; produchig a second mixture from the second selected section; and blending at least a portion ofthe first mixture with at least a portion ofthe second mixture to produce a third mixture comprising a selected property.
681 1. The method of claim 6810, further comprising cold producing the first mixture from the first selected section.
6812. The method ofclaim 6810, wherein producing the ffrst mixture from the first selected section comprises producing the first mixture through a production well in or proximate the foimation.
6813. The method of claim 6810, wherein the selected property of the thfrd mixture comprises an API gravity.
6814. The method ofclaim 6810, wherein the selected property ofthe third mixture comprises a selected viscosity.
6815. The method ofclaim 6810, wherein the selected property ofthe third mixture comprises a density.
6816. The method of claim 6810, wherein the selected property of the third mixture comprises an asphaltene to saturated hydrocarbon ratio of less than about 1.
6817. The method ofclaim 6810, wherein the selected property ofthe thfrd mixture comprises an aromatic hydrocarbon to saturated hydrocarbon ratio of less than about 4.
6818. The method ofclaim 6810, wherein asphaltenes are substantially stable in the third mixture at ambient temperature.
6819. The method ofclaim 6810, wherein the thfrd mixture is transportable.
6820. The method ofclaim 6810, wherein the third mixture is transportable through a pipeline.
6821. The method of claim 6810, wherein the liquid has a viscosity sufficiently high to inhibit economical transport ofthe liquid over 100 km via a pipeline but the mixture has a reduced viscosity that allows economical transport ofthe mixture over 100 km via a pipeline.
6822. The method ofclaim 6810, wherein the first mixture comprises an API gravity less than about 15°.
6823. The method ofclaim 6810, wherein the second mixture comprises an API gravity greater than about 25°.
6824. The method ofclaim 6810, wherein the second mixture comprises an acid number less than about 1.
6825. The method ofclaim 6810, wherein the thfrd mixture comprises less than about 50 % by weight ofthe second mixture.
6826. The method ofclaim 6810, wherein the ffrst selected section comprises a depth of at least about 500 m below the surface of a relatively low permeability formation containing heavy hydrocarbons.
6827. The method ofclaim 6810, wherein the second selected section comprises a depth less than about 500 m below the surface of a relatively low permeability formation containing heavy hydrocarbons.
6828. The method ofclaim 6810, further comprising producing a mixture when a partial pressure ofhydrogen in the formation is at least about 0.5 bars absolute.
6829. The method of claim 6810, wherein the heat provided from at least one heat source is fransfened to at least a portion ofthe formation substantially by conduction.
6830. The method ofclaim 6810, wherein one or more ofthe heat sources comprise heaters.
6831. The method ofclaim 6810, wherein a ratio of energy output ofthe second mixture to energy input into the formation is at least about 5.
6832. A method for treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising: providing heat from one or more heat sources to a selected section of a relatively low permeability formation containing heavy hydrocarbons such that the heat pyrolyzes at least some hydrocarbons within the selected section; producing a blending agent from the selected section; and injecting at least a portion ofthe blending agent into a second section of a relatively low permeability formation containing heavy hydrocarbons to produce a mixture having a selected property, wherein the second section comprises at least some heavy hydrocarbons.
6833. The method of claim 6832, wherein the selected property ofthe mixture comprises an API gravity.
6834. The method ofclaim 6832, wherein the selected property ofthe mixture comprises an API gravity of at least about 10°.
6835. The method ofclaim 6832, wherein the selected property ofthe mixture comprises a selected viscosity.
6836. The method ofclaim 6832, wherein the selected property ofthe mixture comprises a viscosity less than about 7500 cs.
6837. The method ofclaim 6832, wherein the selected property ofthe mixture comprises a density.
6838. The method ofclaim 6832, wherein the selected property ofthe mixture comprises a density less than about 1 g/cm3.
6839. The method ofclaim 6832, wherein the selected property ofthe mixture comprises an asphaltene to saturated hydrocarbon ratio of less than about 1.
6840. The method ofclaim 6832, wherein the selected property ofthe mixture comprises an aromatic hydrocarbon to saturated hydrocarbon ratio of less than about 4.
6841. The method ofclaim 6832, wherein asphaltenes are substantially stable in the mixture at ambient temperature.
6842. The method ofclaim 6832, wherein the mixture is transportable.
6843. The method of claim 6832, wherein the mixture is transportable through a pipeline.
6844. The method ofclaim 6832, wherein second section comprises heavy hydrocarbons having an API gravity less than about 15°.
6845. The method of claim 6832, wherein the blending agent comprises an API gravity greater than about 25°.
6846. The method of claim 6832, wherein the blending agent comprises an acid number less than about 1.
6847. The method of claim 6832, wherein the mixture comprises less than about 50 % by weight ofthe blending agent.
6848. The method ofclaim 6832, wherein the selected section comprises a depth of at least about 500 m below the surface of a relatively low permeability formation containing heavy hydrocarbons.
6849. The method of claim 6832, wherein the second section comprises a depth less than about 500 m below the surface of a relatively low permeability formation containing heavy hydrocarbons.
6850. The method ofclaim 6832, wherein the selected section and the second section are located in different relatively low permeability formations containing heavy hydrocarbons.
6851. The method of claim 6832, wherein the selected section and the second section are located in different relatively low permeability formations containing heavy hydrocarbons, and wherein the different relatively low peπneability formation containing heavy hydrocarbons are vertically displaced.
6852. The method ofclaim 6832, wherein the selected section and the second section are vertically displaced within a single relatively low permeability formation containing heavy hydrocarbons.
6853. The method of clahn 6832, wherein the selected section and the second section are substantially adjacent within a single relatively low permeability formation containing heavy hydrocarbons.
6854. The method of claim 6832, wherein the blending agent is injected into a production well in the second section, and wherein the mixture is produced in the production well.
6855. The method ofclaim 6832, further comprising producing the mixture from the second section.
6856. The method ofclaim 6832, further comprising producing the blending agent when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.
6857. The method ofclaim 6832, wherein the heat provided from at least one heat source is fransfened to at least a portion ofthe formation substantially by conduction.
6858. The method ofclaim 6832, wherein one or more ofthe heat sources comprise heaters.
6859. The method of claim 6832, wherein a ratio of energy output ofthe produced mixture to energy input into the foimation is at least about 5.