CA2606181A1 - Low temperature barriers for use with in situ processes - Google Patents
Low temperature barriers for use with in situ processes Download PDFInfo
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- CA2606181A1 CA2606181A1 CA002606181A CA2606181A CA2606181A1 CA 2606181 A1 CA2606181 A1 CA 2606181A1 CA 002606181 A CA002606181 A CA 002606181A CA 2606181 A CA2606181 A CA 2606181A CA 2606181 A1 CA2606181 A1 CA 2606181A1
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- Prior art keywords
- formation
- freeze
- heat transfer
- transfer fluid
- wells
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
- C10L3/08—Production of synthetic natural gas
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/04—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/17—Interconnecting two or more wells by fracturing or otherwise attacking the formation
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity
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- H—ELECTRICITY
- H05—ELECTRIC TECHNIQUES NOT OTHERWISE PROVIDED FOR
- H05B—ELECTRIC HEATING; ELECTRIC LIGHT SOURCES NOT OTHERWISE PROVIDED FOR; CIRCUIT ARRANGEMENTS FOR ELECTRIC LIGHT SOURCES, IN GENERAL
- H05B2214/00—Aspects relating to resistive heating, induction heating and heating using microwaves, covered by groups H05B3/00, H05B6/00
- H05B2214/03—Heating of hydrocarbons
Abstract
A heating system for a subsurface formation is described. The heating system includes a first heater, a second heater, and a third heater placed in an opening in the subsurface formation. Each heater includes: an electrical conductor; an insulation layer at least partially surrounding the electrical conductor; and an electrically conductive sheath at least partially surrounding the insulation layer. The electrical conductor is electrically coupled to the sheath at a lower end portion of the heater. The lower end portion is the portion of the heater distal from a surface of the opening. The first heater, the second heater, and the third heater are electrically coupled at the lower end portions of the heaters. The first heater, the second heater, and the third heater are configured to be electrically coupled in a three-phase wye configuration.
Description
'i'6W+E1VI&60URE BARRIERS FOR USE WITH IN SITU PROCESSES
BACKGROUND
1. Field of the Invention The present invention relates generally to methods and systems for providing a barrier around at least a portion of a subsurface treatment area. The treatment area may be utilized for the production of hydrocarbons, hydrogen, and/or other products. Embodiments relate to the forma.tion of a low temperature barrier around at least a portion of a treatment area.
BACKGROUND
1. Field of the Invention The present invention relates generally to methods and systems for providing a barrier around at least a portion of a subsurface treatment area. The treatment area may be utilized for the production of hydrocarbons, hydrogen, and/or other products. Embodiments relate to the forma.tion of a low temperature barrier around at least a portion of a treatment area.
2. Description of Related Art In situ processes may be used to treat subsurface formations. During some in situ processes, fluids may be introduced or generated in the formation. Introduced or generated fluids may need to be contained in a treatment area to niinimize or eliminate impact of the in situ process on adjacent areas. During some in situ processes, a barrier may be formed around all or a portion of the treatment area to inhibit migration fluids out of or into the treatment area.
A low temperature zone may, be used to isolate selected areas of subsurface formation for many purposes.
In some systems, ground is frozen to inhibit migration of fluids from a treatment area during soil remediation. U.S.
Patent Nos. 4,860,544 to Krieg et al., 4,974,425 to Krieg et al.; 5,507,149 to Dash et al., 6,796,139 to Briley et al.;
and 6,854,929 to Vinegar et al. describe systems for freezing ground.
To form a low temperature barrier, spaced apart wellbores may be formed in the formation where the barrier is to be formed. Piping may be placed in the wellbores. A low temperature heat transfer fluid may be circulated through the piping to reduce the temperature adjacent to the wellbores. The low temperature zone around the wellbores may expand outward. Eventually the low temperature zones produced by two adjacent wellbores merge. The temperature of the low temperature zones may be sufficiently low to freeze formation fluid so that a substantially impermeable barrier is formed. The wellbore spacing may be from about 1 m to 3 m or more.
Wellbore spacing may be a function of a number of factors, including formation composition and properties, formation fluid and properties, time available for forming the barrier, and temperature and properties of the low temperature heat transfer fluid. In general, a very cold temperature of the low temperature heat transfer fluid allows for a larger spacing and/or for quicker formation of the barrier. A
very cold temperature may be -20 C or less.
Producing a very cold temperature heat transfer fluid may be problematic. In addition, the use of very cold temperature heat transfer fluid may require the use of special, high cost materials in the wellbores to accommodate the low temperatures. Therefore, it is desirable to have a system that can produce a low temperature barrier using a reasonable well spacing without the need for very cold temperatures and the use of special, high cost materials for forming the freeze wells.
SUMMARY
Embodiments described herein generally relate to systems, and methods providing a barrier around at least a portion of a subsurface treatment area.
In some embodiments, the invention provides a system for forming a freeze barrier around at least a portion of a subsurface treatment area, that includes a plurality of freeze wells, wherein at least one freeze wells positioned in the ground comprises a carbon steel canister; heat transfer fluid; and a refrigeration system configured to supply the heat transfer fluid to the freeze wells, wherein the refrigeration system is configured to cool the heat transfer fluid to a temperatttre tltat allriwstnL- neat,transter fluid provided to a first freeze well to be in a range from -35 C to -55 oc.
The invention also provides methods of forming and maintaining the low temperature zone of the described invention.
In further embodiments, features from specific embodiments may, be combined with features from other embodiments. For example, features from one embodiment may be combined with features from any of the other embodiments.
In further embodiments, treating a subsurface formation is performed using any of the methods or systems described herein.
In further embodiments, additional features may be added to the specific embodiments described herein.
BRIEF DESCRIPTION OF THE DRAWINGS
Advantages of the present invention may become apparent to those skilled in the art with the benefit of the following detailed description and upon reference to the accompanying drawings in which:
FIG. 1 shows a schematic view of an embodiment of a portion of an in situ conversion system for treating a hydrocarbon containing fornnation.
FIG. 2 depicts an embodiment of a freeze well for a circulated liquid refrigeration sy,stem, wherein a cutaway view of the freeze well is represented below ground surface.
FIG. 3 depicts a schematic representation of an embodiment of a refrigeration system for forming a low temperature zone around a treatment area.
FIG. 4 depicts a schematic view of a well layout including heat interceptor wells.
While the invention is susceptible to various modifications and alternative forms, specific embodiments thereof are shown by way of example in the drawings and may herein be described in detail. The drawings may not be to scale. It should be understood, however, that the drawings and detailed description thereto are not intended to limit the invention to the particular form disclosed, but on the contrary, the intention is to cover all modifications, equivalents and alternatives falling within the spirit and scope of the present invention as defined by the appended claims.
DETAILED DESCRIPTION
The following description generally relates to systems and methods for treating hydrocarbons in formations.
Formations may be treated using in situ conversion processes to yield hydrocarbon products, hydrogen, and other products. Freeze wells may be used to form a barrier around all or a portion of a formation being subjected to an in situ conversion process.
"Hydrocarbons" are generally defmed as molecules formed primarily by carbon and hydrogen atoms.
Hydrocarbons may also include other elements such as, but not limited to, halogens, metallic elements, nitrogen, oxygen, and/or sulfur. Hydrocarbons may be, but are not limited to, kerogen, bitumen, pyrobitumen, oils, natural mineral waxes, and asphaltites. Hydrocarbons may be located in or adjacent to mineral matrices in the earth.
Matrices may include, but are not limited to, sedimentary rock, sands, silicilytes, carbonates, diatomites, and other porous media. "Hydrocarbon fluids" are fluids that include hydrocarbons.
Hydrocarbon fluids may include, entrain, or be entrained in non-hydrocarbon fluids such as hydrogen, nitrogen, carbon monoxide, carbon dioxide, hydrogen sulfide, water, and ammonia.
A"formation" includes one or more hydrocarbon containing layers, one or more non-hydrocarbon layers, an overburden, and/or an underburden. The "overburden" and/or the "underburden" include one or more different "' es of im"errhe~'lil'e iri'~dle~'ia'1'~. "'For'example, overburden and/or underburden may rock, shale, mudstone, ~Y Pinclude or wet/tight carbonate. In some embodiments of in situ conversion processes, the overburden and/or the underburden may include a hydrocarbon containing layer or hydrocarbon containing layers that are relatively impermeable and are not subjected to temperatures during in situ conversion processing that result in significant characteristic changes of the hydrocarbon containing layers of the overburden and/or the underburden. For example, the underburden may contain shale or mudstone, but the underburden is not allowed to heat to pyrolysis temperatures during the in situ conversion process. In some cases, the overburden and/or the underburden may be somewhat permeable.
"Formation fluids" refer to fluids present in a formation and may include p-yrolyzation fluid, synthesis gas, mobilized hydrocarbon, and water (steam). Formation fluids may include hydrocarbon fluids as well as. non-hydrocarbon fluids. The term "mobilized fluid" refers to fluids in a hydrocarbon containing formation that are able to flow as a result of thermal treatment of the formation. "Produced fluids"
refer to formation fluids removed from the formation.
A "heat source" is any system for providing heat to at least a portion of a formation substantially by conductive and/or radiative heat transfer. For example, a heat source may include electric heaters such as an insulated conductor, an elongated member, and/or a conductor disposed in a conduit. A heat source may also include systems that generate heat by burning a fuel external to or in a formation. The systems may be surface burners, downhole gas burners, flameless distributed combustors, and natural distributed combustors. In some embodiments, heat provided to or generated in one or more heat sources may be supplied by other sources of energy.
The other sources of energy may directly heat a formation, or the energy may be applied to a transfer medium that directly or indirectly heats the formation. It is to be understood that one or more heat sources that are applying heat to a formation may use different sources of energy. Thus, for example, for a given formation some heat sources may supply heat from electric resistance heaters, some heat sources may provide heat from combustion, and some heat sources may provide heat from one or more other energy sources (for example, chemical reactions, solar energy, wind energy, biomass, or other sources of renewable energy). A chemical reaction may include an exothermic reaction (for example, an oxidation reaction). A heat source may also include a heater that provides heat to a zone proximate and/or surrounding a heating location such as a heater well.
A"heater" is any system or heat source for generating heat in a well or a near wellbore region. Heaters may be, but are not limited to, electric heaters, burners, combustors that react with material in or produced from a formation, and/or combinations thereof.
An "in situ conversion process" refers to a process of heating a hydrocarbon containing formation from heat sources to raise the temperature of at least a portion of the formation above a pyrolysis temperature so that pyrolyzation fluid is produced in the formation.
The term "wellbore" refers to a hole in a formation made by drilling or insertion of a conduit into the formation. A wellbore may have a substantially circular cross section, or another cross-sectional shape. As used herein, the terms "well" and "opening," when referring to an opening in the formation may be used interchangeably with the term "wellbore."
"Pyrolysis" is the breaking of chemical bonds due to the application of heat.
For example, pyrolysis may include transforming a compound into one or more other substances by heat alone. Heat may be transferred to a section of the formation to cause pyrolysis. In some formations, portions of the formation and/or other materials in the formation may promote pyrolysis through catalytic activity.
A low temperature zone may, be used to isolate selected areas of subsurface formation for many purposes.
In some systems, ground is frozen to inhibit migration of fluids from a treatment area during soil remediation. U.S.
Patent Nos. 4,860,544 to Krieg et al., 4,974,425 to Krieg et al.; 5,507,149 to Dash et al., 6,796,139 to Briley et al.;
and 6,854,929 to Vinegar et al. describe systems for freezing ground.
To form a low temperature barrier, spaced apart wellbores may be formed in the formation where the barrier is to be formed. Piping may be placed in the wellbores. A low temperature heat transfer fluid may be circulated through the piping to reduce the temperature adjacent to the wellbores. The low temperature zone around the wellbores may expand outward. Eventually the low temperature zones produced by two adjacent wellbores merge. The temperature of the low temperature zones may be sufficiently low to freeze formation fluid so that a substantially impermeable barrier is formed. The wellbore spacing may be from about 1 m to 3 m or more.
Wellbore spacing may be a function of a number of factors, including formation composition and properties, formation fluid and properties, time available for forming the barrier, and temperature and properties of the low temperature heat transfer fluid. In general, a very cold temperature of the low temperature heat transfer fluid allows for a larger spacing and/or for quicker formation of the barrier. A
very cold temperature may be -20 C or less.
Producing a very cold temperature heat transfer fluid may be problematic. In addition, the use of very cold temperature heat transfer fluid may require the use of special, high cost materials in the wellbores to accommodate the low temperatures. Therefore, it is desirable to have a system that can produce a low temperature barrier using a reasonable well spacing without the need for very cold temperatures and the use of special, high cost materials for forming the freeze wells.
SUMMARY
Embodiments described herein generally relate to systems, and methods providing a barrier around at least a portion of a subsurface treatment area.
In some embodiments, the invention provides a system for forming a freeze barrier around at least a portion of a subsurface treatment area, that includes a plurality of freeze wells, wherein at least one freeze wells positioned in the ground comprises a carbon steel canister; heat transfer fluid; and a refrigeration system configured to supply the heat transfer fluid to the freeze wells, wherein the refrigeration system is configured to cool the heat transfer fluid to a temperatttre tltat allriwstnL- neat,transter fluid provided to a first freeze well to be in a range from -35 C to -55 oc.
The invention also provides methods of forming and maintaining the low temperature zone of the described invention.
In further embodiments, features from specific embodiments may, be combined with features from other embodiments. For example, features from one embodiment may be combined with features from any of the other embodiments.
In further embodiments, treating a subsurface formation is performed using any of the methods or systems described herein.
In further embodiments, additional features may be added to the specific embodiments described herein.
BRIEF DESCRIPTION OF THE DRAWINGS
Advantages of the present invention may become apparent to those skilled in the art with the benefit of the following detailed description and upon reference to the accompanying drawings in which:
FIG. 1 shows a schematic view of an embodiment of a portion of an in situ conversion system for treating a hydrocarbon containing fornnation.
FIG. 2 depicts an embodiment of a freeze well for a circulated liquid refrigeration sy,stem, wherein a cutaway view of the freeze well is represented below ground surface.
FIG. 3 depicts a schematic representation of an embodiment of a refrigeration system for forming a low temperature zone around a treatment area.
FIG. 4 depicts a schematic view of a well layout including heat interceptor wells.
While the invention is susceptible to various modifications and alternative forms, specific embodiments thereof are shown by way of example in the drawings and may herein be described in detail. The drawings may not be to scale. It should be understood, however, that the drawings and detailed description thereto are not intended to limit the invention to the particular form disclosed, but on the contrary, the intention is to cover all modifications, equivalents and alternatives falling within the spirit and scope of the present invention as defined by the appended claims.
DETAILED DESCRIPTION
The following description generally relates to systems and methods for treating hydrocarbons in formations.
Formations may be treated using in situ conversion processes to yield hydrocarbon products, hydrogen, and other products. Freeze wells may be used to form a barrier around all or a portion of a formation being subjected to an in situ conversion process.
"Hydrocarbons" are generally defmed as molecules formed primarily by carbon and hydrogen atoms.
Hydrocarbons may also include other elements such as, but not limited to, halogens, metallic elements, nitrogen, oxygen, and/or sulfur. Hydrocarbons may be, but are not limited to, kerogen, bitumen, pyrobitumen, oils, natural mineral waxes, and asphaltites. Hydrocarbons may be located in or adjacent to mineral matrices in the earth.
Matrices may include, but are not limited to, sedimentary rock, sands, silicilytes, carbonates, diatomites, and other porous media. "Hydrocarbon fluids" are fluids that include hydrocarbons.
Hydrocarbon fluids may include, entrain, or be entrained in non-hydrocarbon fluids such as hydrogen, nitrogen, carbon monoxide, carbon dioxide, hydrogen sulfide, water, and ammonia.
A"formation" includes one or more hydrocarbon containing layers, one or more non-hydrocarbon layers, an overburden, and/or an underburden. The "overburden" and/or the "underburden" include one or more different "' es of im"errhe~'lil'e iri'~dle~'ia'1'~. "'For'example, overburden and/or underburden may rock, shale, mudstone, ~Y Pinclude or wet/tight carbonate. In some embodiments of in situ conversion processes, the overburden and/or the underburden may include a hydrocarbon containing layer or hydrocarbon containing layers that are relatively impermeable and are not subjected to temperatures during in situ conversion processing that result in significant characteristic changes of the hydrocarbon containing layers of the overburden and/or the underburden. For example, the underburden may contain shale or mudstone, but the underburden is not allowed to heat to pyrolysis temperatures during the in situ conversion process. In some cases, the overburden and/or the underburden may be somewhat permeable.
"Formation fluids" refer to fluids present in a formation and may include p-yrolyzation fluid, synthesis gas, mobilized hydrocarbon, and water (steam). Formation fluids may include hydrocarbon fluids as well as. non-hydrocarbon fluids. The term "mobilized fluid" refers to fluids in a hydrocarbon containing formation that are able to flow as a result of thermal treatment of the formation. "Produced fluids"
refer to formation fluids removed from the formation.
A "heat source" is any system for providing heat to at least a portion of a formation substantially by conductive and/or radiative heat transfer. For example, a heat source may include electric heaters such as an insulated conductor, an elongated member, and/or a conductor disposed in a conduit. A heat source may also include systems that generate heat by burning a fuel external to or in a formation. The systems may be surface burners, downhole gas burners, flameless distributed combustors, and natural distributed combustors. In some embodiments, heat provided to or generated in one or more heat sources may be supplied by other sources of energy.
The other sources of energy may directly heat a formation, or the energy may be applied to a transfer medium that directly or indirectly heats the formation. It is to be understood that one or more heat sources that are applying heat to a formation may use different sources of energy. Thus, for example, for a given formation some heat sources may supply heat from electric resistance heaters, some heat sources may provide heat from combustion, and some heat sources may provide heat from one or more other energy sources (for example, chemical reactions, solar energy, wind energy, biomass, or other sources of renewable energy). A chemical reaction may include an exothermic reaction (for example, an oxidation reaction). A heat source may also include a heater that provides heat to a zone proximate and/or surrounding a heating location such as a heater well.
A"heater" is any system or heat source for generating heat in a well or a near wellbore region. Heaters may be, but are not limited to, electric heaters, burners, combustors that react with material in or produced from a formation, and/or combinations thereof.
An "in situ conversion process" refers to a process of heating a hydrocarbon containing formation from heat sources to raise the temperature of at least a portion of the formation above a pyrolysis temperature so that pyrolyzation fluid is produced in the formation.
The term "wellbore" refers to a hole in a formation made by drilling or insertion of a conduit into the formation. A wellbore may have a substantially circular cross section, or another cross-sectional shape. As used herein, the terms "well" and "opening," when referring to an opening in the formation may be used interchangeably with the term "wellbore."
"Pyrolysis" is the breaking of chemical bonds due to the application of heat.
For example, pyrolysis may include transforming a compound into one or more other substances by heat alone. Heat may be transferred to a section of the formation to cause pyrolysis. In some formations, portions of the formation and/or other materials in the formation may promote pyrolysis through catalytic activity.
""Thei=mal'cond"uciivii yis a'property of a material that describes the rate at which heat flows, in steady state, between two surfaces of the material for a given temperature difference between the two surfaces.
Hydrocarbons or other desired products in a formation may be produced using various in situ processes.
Some in situ processes that may be used to produce hydrocarbons or desired products are in situ conversion processes, steam flooding, fire flooding, steam-assisted gravity drainage, and solution mining. During some in situ processes, barriers may be needed or required. Barriers may, inhibit fluid, such as formation water, from entering a treatment area. Barriers may also inhibit undesired exit of fluid from the treatment area. Inhibiting undesired exit of fluid from the treatment area may minimize or eliminate impact of the in situ process on areas adjacent to the treatment area.
FIG. 1 depicts a schematic view of an embodiment of a portion of in situ conversion system 100 for treating a hydrocarbon containing formation. In situ conversion system 100 may include barrier wells 102. Barrier wells 102 are used to form a barrier around a treatment area. The barrier inhibits fluid flow into and/or out of the treatment area. Barrier wells include, but are not limited to, dewatering wells, vacuum wells, capture wells, injection wells, grout wells, freeze wells, or combinations thereof. In the embodiment depicted in FIG. 1, barrier wells 102 are shown extending only, along one side of heat sources 104, but the barrier wells typically encircle all heat sources 104 used, or to be used, to heat a treatment area of the formation.
Heat sources 104 are placed in at least a portion of the formation. Heat sources 104 may include heaters such as insulated conductors, conductor-in-conduit heaters, surface burners, flameless distributed combustors, and/or natural distributed combustors. Heat sources 104 may also include other types of heaters. Heat sources 104 provide heat to at least a portion of the fonnation to heat hydrocarbons in the formation. Energy may be supplied to heat sources 104 through supply lines 106. Supply lines 106 may be structurally different depending on the type of heat source or heat sources used to heat the formation. Supply lines 106 for heat sources may transmit electricity for electric heaters, may transport fuel for combustors, or may transport heat exchange fluid that is circulated in the formation.
Production wells 108 are used to remove formation fluid from the formation. In some embodiments, production well 108 may include one or more heat sources. A heat source in the production well may heat one or more portions of the formation at or near the production well. A heat source in a production well may inhibit condensation and reflux of formation fluid being removed from the formation.
Formation fluid produced from production wells 108 may be transported through collection piping 110 to treatment facilities 112. Formation fluids may also be produced from heat sources 104. For example, fluid may be produced from heat sources 104 to control pressure in the formation adjacent to the heat sources. Fluid produced from heat sources 104 may be transported through tubing or piping to collection piping 110 or the produced fluid may be transported through tubing or piping directly to treatment facilities 112. Treatment facilities 112 may include separation units, reaction units, upgrading units, fuel cells, turbines, storage vessels, and/or other systems and units for processing produced formation fluids. The treatment facilities may form transportation fuel from at least a portion of the hydrocarbons produced from the formation.
Some wellbores formed in the formation may be used to facilitate formation of a perimeter barrier around a treatment area. The perimeter barrier may be, but is not limited to, a low temperature or frozen barrier formed by freeze wells, dewatering wells, a grout wall formed in the formation, a sulfur cement barrier, a barrier formed by a gel produced in the formation, a barrier formed by precipitation of salts in the formation, a barrier formed by a polymerization reaction in the formation, and/or sheets driven into the formation. Heat sources, production wells, " mjectiori w~7is;'ti~~i2['teriYng"v~~Tls;"~nd/or monitoring wells may be installed in the treatment area defmed by the barrier prior to, simultaneously with, or after installation of the barrier.
A low temperature zone around at least a portion of a treatment area may be formed by freeze wells. In an embodiment, refrigerant is circulated through freeze wells to form low temperature zones around each freeze well.
The freeze wells are placed in the formation so that the low temperature zones overlap and form a low temperature zone around the treatment area. The low temperature zone established by freeze wells is maintained below the freezing temperature of aqueous fluid in the formation. Aqueous fluid entering the low temperature zone freezes and forms the frozen barrier. In other embodiments, the freeze barrier is formed by batch operated freeze wells. A cold fluid, such as liquid nitrogen, is introduced into the freeze wells to form low temperature zones around the freeze wells. The fluid is replenished as needed.
In some embodiments, two or more rows of freeze wells are located about all or a portion of the perimeter of the treatment area to form a thick interconnected low temperature zone.
Thick low temperature zones may be formed adjacent to areas in the formation where there is a high flow rate of aqueous fluid in the formation. The thick barrier may ensure that breakthrough of the frozen barrier established by the freeze wells does not occur.
Vertically positioned freeze wells and/or horizontally positioned freeze wells may be positioned around sides of the treatment area. If the upper layer (the overburden) or the lower layer (the underburden) of the formation is likely to allow fluid flow into the treatment area or out of the treatment area, horizontally positioned freeze wells may be used to form an upper and/or a lower barrier for the treatment area. In some embodiments, an upper barrier and/or a lower barrier may not be necessary if the upper layer and/or the lower layer are at least substantially impermeable. If the upper freeze barrier is formed, portions of heat sources, production wells, injection wells, and/or dewatering wells that pass through the low temperature zone created by the freeze wells forming the upper freeze barrier wells may be insulated and/or heat traced so that the low temperature zone does not adversely affect the functioning of the heat sources, production wells, injection wells and/or dewatering wells passing through the low temperature zone.
Spacing between adjacent freeze wells may be a function of a number of different factors. The factors may include, but are not limited to, physical properties of formation material, type of refrigeration system, coldness and thermal properties of the refrigerant, flow rate of material into or out of the treatment area, time for forming the low temperature zone, and economic considerations. Consolidated or partially consolidated formation material may allow for a large separation distance between freeze wells. A separation distance between freeze wells in consolidated or partially consolidated formation material may be from about 3 m to about 20 m, about 4 m to about 15 m, or about 5 m to about 10 m. In an embodiment, the spacing between adjacent freeze wells is about 5 m.
Spacing between freeze wells in unconsolidated or substantially unconsolidated formation material, such as in tar sand, may need to be smaller than spacing in consolidated formation material.
A separation distance between freeze wells in unconsolidated material may be from about 1 m to about 5 m.
Freeze wells may be placed in the formation so that there is minimal deviation in orientation of one freeze well relative to an adjacent freeze well. Excessive deviation may create a large separation distance between adjacent freeze wells that may not pemzit formation of an interconnected low temperature zone between the adjacent freeze wells. Factors that influence the manner in which freeze wells are inserted into the ground include, but are not limited to, freeze well insertion time, depth that the freeze wells are to be inserted, formation properties, desired well orientation, and economics.
~4 vklb1bres for freeze wells may be impacted and/or vibrationally inserted into some formations. Wellbores for freeze wells may be impacted and/or vibrationally inserted into formations to depths from about 1 m to about 100 m without excessive deviation in orientation of freeze wells relative to adjacent freeze wells in some types of formations.
Wellbores for freeze wells placed deep in the formation, or wellbores for freeze wells placed in formations with layers that are difficult to impact or vibrate a well through, may be placed in the formation by directional drilling and/or geosteering. Acoustic signals, electrical signals, magnetic signals, and/or other signals produced in a first wellbore may be used to guide drilling of adjacent wellbores so that desired spacing between adjacent wells is maintained. Tight control of the spacing between wellbores for freeze wells is an important factor in minimizing the time for completion of barrier formation.
After formation of the wellbore for the freeze well, the wellbore may be backflushed with water adjacent to the part of the formation that is to be reduced in temperature to form a portion of the freeze barrier. The water may displace drilling fluid remaining in the wellbore. The water may displace indigenous gas in cavities adjacent to the formation. In some embodiments, the wellbore is filled with water from a conduit up to the level of the overburden.
In some embodiments, the wellbore is backflushed with water in sections. The wellbore maybe treated in sections having lengths of about 6 m, 10 m, 14 m, 17 m, or greater. Pressure of the water in the wellbore is maintained below the fracture pressure of the formation. In some embodiments, the water, or a portion of the water is removed from the wellbore, and a freeze well is placed in the formation.
FIG. 2 depicts an embodiment of freeze well 114. Freeze well 114 may include canister 116, inlet conduit 118, spacers 120, and wellcap 122. Spacers 120 may position inlet conduit 118 in canister 116 so that an annular space is formed between the canister and the conduit. Spacers 120 may promote turbulent flow of refrigerant in the annular space between inlet conduit 118 and canister 116, but the spacers may also cause a significant fluid pressure drop. Turbulent fluid flow in the annular space may be promoted by roughening the inner surface of canister 116, by roughening the outer surface of inlet conduit 118, and/or by having a small cross-sectional area annular space that allows for high refrigerant velocity in the annular space. In some embodiments, spacers are not used. Wellhead 123 may suspend canister 116 in wellbore 125.
Formation refrigerant may flow through cold side conduit 124 from a refrigeration unit to inlet conduit 118 of freeze well 114. The formation refrigerant may flow through an annular space between inlet conduit 118 and canister 116 to warm side conduit 126. Heat may transfer from the formation to canister 116 and from the canister to the formation refrigerant in the annular space. Inlet conduit 118 may be insulated to inhibit heat transfer to the formation refrigerant during passage of the formation refrigerant into freeze well 114. In an embodiment, inlet conduit 118 is a high density polyethylene tube. At cold temperatures, some polymers may exhibit a large amount of thermal contraction. For example, a 260 m initial length of polyethylene conduit subjected to a temperature of about -25 C may contract by 6 m or more. If a high density polyethylene conduit, or other polymer conduit, is used, the large thermal contraction of the material must be taken into account in determining the fmal depth of the freeze well.
For example, the freeze well may be drilled deeper than needed, and the conduit may be allowed to shrink back during use. In some embodiments, inlet conduit 118 is an insulated metal tube.
In some embodiments, the insulation may be a polymer coating, such as, but not limited to, polyvinylchloride, high density polyethylene, and/or polystyrene.
Freeze well 114 may be introduced into the formation using a coiled tubing rig. In an embodiment, canister 116 and inlet conduit 118 are wound on a single reel. The coiled tubing rig introduces the canister and inlet conduit Y'18'in'Eo Ifi-auf'e$iMu~rient, canister 116 is wound on a first reel and inlet conduit 118 is wound on a second reel. The coiled tubing rig introduces canister 116 into the formation.
Then, the coiled tubing rig is used to introduce inlet conduit 118 into the canister. In other embodiments, freeze well is assembled in sections at the wellbore site and introduced into the formation.
An insulated section of freeze well 114 may be placed adjacent to overburden 128. An uninsulated section of freeze well 114 may be placed adjacent to layer or layers 130 where a low temperature zone is to be formed. In some embodiments, uninsulated sections of the freeze wells may be positioned adjacent only to aquifers or other permeable portions of the formation that would allow fluid to flow into or out of the treatment area. Portions of the formation where uninsulated sections of the freeze wells are to be placed may be determined using analysis of cores and/or logging techniques.
Various types of refrigeration systems may be used to form a low temperature zone. Determination of an appropriate refrigeration system may be based on many factors, including, but not limited to: type of freeze well; a distance between adjacent freeze wells; refrigerant; time frame in which to form a low temperature zone; depth of the low temperature zone; temperature differential to which the refrigerant will be subjected; chemical and physical properties of the refrigerant; environmental concerns related to potential refrigerant releases, leaks, or spills;
economics; formation water flow in the forniation; composition and properties of formation water, including the salinity of the formation water; and various properties of the formation such as thermal conductivity, thermal diffusivity, and heat capacity.
A circulated fluid refrigeration system may utilize a liquid refrigerant (forma.tion refrigerant) that is circulated through freeze wells. Some of the desired properties for the formation refrigerant are: low working temperature, low viscosity at and near the working temperature, high density, high specific heat capacity, high thermal conductivity, low cost, low corrosiveness, and low toxicity. A low working temperature of the formation refrigerant allows a large low temperature zone to be established around a freeze well. The low working temperature of formation refrigerant should be about -20 C or lower. Formation refrigerants having low working temperatures of at least -60 C may include aqua ammonia, potassium formate solutions such as Dynalene HC-50 (Dynalene Heat Transfer Fluids (Whitehall, Pennsylvania, U.S.A.)) or FREEZIUM (Kemira Chemicals (Helsinki, Finland));
silicone heat transfer fluids such as Syltherm XLT (Dow Corning Corporation (Midland, Michigan, U.S.A.);
hydrocarbon refrigerants such as propylene; and chlorofluorocarbons such as R-22. Aqua annnonia is a solution of anunonia and water with a weight percent of ammonia between about 20% and about 40%. Aqua annnonia has several properties and characteristics that make use of aqua ammonia as the formation refrigerant desirable. Such properties and characteristics include, but are not limited to, a very low freezing point, a low viscosity, ready availability, and low cost.
Formation refrigerant that is capable of being chilled below a freezing temperature of aqueous formation fluid may be used to form the low temperature zone around the treatment area.
The following equation (the Sanger equation) may be used to model the time t, needed to form a frozen barrier of radius R around a freeze well having a surface temperature of Ts:
(1) t1= RzL' 21nR-l+c fvs 4k fvs r0 L, in which:
Hydrocarbons or other desired products in a formation may be produced using various in situ processes.
Some in situ processes that may be used to produce hydrocarbons or desired products are in situ conversion processes, steam flooding, fire flooding, steam-assisted gravity drainage, and solution mining. During some in situ processes, barriers may be needed or required. Barriers may, inhibit fluid, such as formation water, from entering a treatment area. Barriers may also inhibit undesired exit of fluid from the treatment area. Inhibiting undesired exit of fluid from the treatment area may minimize or eliminate impact of the in situ process on areas adjacent to the treatment area.
FIG. 1 depicts a schematic view of an embodiment of a portion of in situ conversion system 100 for treating a hydrocarbon containing formation. In situ conversion system 100 may include barrier wells 102. Barrier wells 102 are used to form a barrier around a treatment area. The barrier inhibits fluid flow into and/or out of the treatment area. Barrier wells include, but are not limited to, dewatering wells, vacuum wells, capture wells, injection wells, grout wells, freeze wells, or combinations thereof. In the embodiment depicted in FIG. 1, barrier wells 102 are shown extending only, along one side of heat sources 104, but the barrier wells typically encircle all heat sources 104 used, or to be used, to heat a treatment area of the formation.
Heat sources 104 are placed in at least a portion of the formation. Heat sources 104 may include heaters such as insulated conductors, conductor-in-conduit heaters, surface burners, flameless distributed combustors, and/or natural distributed combustors. Heat sources 104 may also include other types of heaters. Heat sources 104 provide heat to at least a portion of the fonnation to heat hydrocarbons in the formation. Energy may be supplied to heat sources 104 through supply lines 106. Supply lines 106 may be structurally different depending on the type of heat source or heat sources used to heat the formation. Supply lines 106 for heat sources may transmit electricity for electric heaters, may transport fuel for combustors, or may transport heat exchange fluid that is circulated in the formation.
Production wells 108 are used to remove formation fluid from the formation. In some embodiments, production well 108 may include one or more heat sources. A heat source in the production well may heat one or more portions of the formation at or near the production well. A heat source in a production well may inhibit condensation and reflux of formation fluid being removed from the formation.
Formation fluid produced from production wells 108 may be transported through collection piping 110 to treatment facilities 112. Formation fluids may also be produced from heat sources 104. For example, fluid may be produced from heat sources 104 to control pressure in the formation adjacent to the heat sources. Fluid produced from heat sources 104 may be transported through tubing or piping to collection piping 110 or the produced fluid may be transported through tubing or piping directly to treatment facilities 112. Treatment facilities 112 may include separation units, reaction units, upgrading units, fuel cells, turbines, storage vessels, and/or other systems and units for processing produced formation fluids. The treatment facilities may form transportation fuel from at least a portion of the hydrocarbons produced from the formation.
Some wellbores formed in the formation may be used to facilitate formation of a perimeter barrier around a treatment area. The perimeter barrier may be, but is not limited to, a low temperature or frozen barrier formed by freeze wells, dewatering wells, a grout wall formed in the formation, a sulfur cement barrier, a barrier formed by a gel produced in the formation, a barrier formed by precipitation of salts in the formation, a barrier formed by a polymerization reaction in the formation, and/or sheets driven into the formation. Heat sources, production wells, " mjectiori w~7is;'ti~~i2['teriYng"v~~Tls;"~nd/or monitoring wells may be installed in the treatment area defmed by the barrier prior to, simultaneously with, or after installation of the barrier.
A low temperature zone around at least a portion of a treatment area may be formed by freeze wells. In an embodiment, refrigerant is circulated through freeze wells to form low temperature zones around each freeze well.
The freeze wells are placed in the formation so that the low temperature zones overlap and form a low temperature zone around the treatment area. The low temperature zone established by freeze wells is maintained below the freezing temperature of aqueous fluid in the formation. Aqueous fluid entering the low temperature zone freezes and forms the frozen barrier. In other embodiments, the freeze barrier is formed by batch operated freeze wells. A cold fluid, such as liquid nitrogen, is introduced into the freeze wells to form low temperature zones around the freeze wells. The fluid is replenished as needed.
In some embodiments, two or more rows of freeze wells are located about all or a portion of the perimeter of the treatment area to form a thick interconnected low temperature zone.
Thick low temperature zones may be formed adjacent to areas in the formation where there is a high flow rate of aqueous fluid in the formation. The thick barrier may ensure that breakthrough of the frozen barrier established by the freeze wells does not occur.
Vertically positioned freeze wells and/or horizontally positioned freeze wells may be positioned around sides of the treatment area. If the upper layer (the overburden) or the lower layer (the underburden) of the formation is likely to allow fluid flow into the treatment area or out of the treatment area, horizontally positioned freeze wells may be used to form an upper and/or a lower barrier for the treatment area. In some embodiments, an upper barrier and/or a lower barrier may not be necessary if the upper layer and/or the lower layer are at least substantially impermeable. If the upper freeze barrier is formed, portions of heat sources, production wells, injection wells, and/or dewatering wells that pass through the low temperature zone created by the freeze wells forming the upper freeze barrier wells may be insulated and/or heat traced so that the low temperature zone does not adversely affect the functioning of the heat sources, production wells, injection wells and/or dewatering wells passing through the low temperature zone.
Spacing between adjacent freeze wells may be a function of a number of different factors. The factors may include, but are not limited to, physical properties of formation material, type of refrigeration system, coldness and thermal properties of the refrigerant, flow rate of material into or out of the treatment area, time for forming the low temperature zone, and economic considerations. Consolidated or partially consolidated formation material may allow for a large separation distance between freeze wells. A separation distance between freeze wells in consolidated or partially consolidated formation material may be from about 3 m to about 20 m, about 4 m to about 15 m, or about 5 m to about 10 m. In an embodiment, the spacing between adjacent freeze wells is about 5 m.
Spacing between freeze wells in unconsolidated or substantially unconsolidated formation material, such as in tar sand, may need to be smaller than spacing in consolidated formation material.
A separation distance between freeze wells in unconsolidated material may be from about 1 m to about 5 m.
Freeze wells may be placed in the formation so that there is minimal deviation in orientation of one freeze well relative to an adjacent freeze well. Excessive deviation may create a large separation distance between adjacent freeze wells that may not pemzit formation of an interconnected low temperature zone between the adjacent freeze wells. Factors that influence the manner in which freeze wells are inserted into the ground include, but are not limited to, freeze well insertion time, depth that the freeze wells are to be inserted, formation properties, desired well orientation, and economics.
~4 vklb1bres for freeze wells may be impacted and/or vibrationally inserted into some formations. Wellbores for freeze wells may be impacted and/or vibrationally inserted into formations to depths from about 1 m to about 100 m without excessive deviation in orientation of freeze wells relative to adjacent freeze wells in some types of formations.
Wellbores for freeze wells placed deep in the formation, or wellbores for freeze wells placed in formations with layers that are difficult to impact or vibrate a well through, may be placed in the formation by directional drilling and/or geosteering. Acoustic signals, electrical signals, magnetic signals, and/or other signals produced in a first wellbore may be used to guide drilling of adjacent wellbores so that desired spacing between adjacent wells is maintained. Tight control of the spacing between wellbores for freeze wells is an important factor in minimizing the time for completion of barrier formation.
After formation of the wellbore for the freeze well, the wellbore may be backflushed with water adjacent to the part of the formation that is to be reduced in temperature to form a portion of the freeze barrier. The water may displace drilling fluid remaining in the wellbore. The water may displace indigenous gas in cavities adjacent to the formation. In some embodiments, the wellbore is filled with water from a conduit up to the level of the overburden.
In some embodiments, the wellbore is backflushed with water in sections. The wellbore maybe treated in sections having lengths of about 6 m, 10 m, 14 m, 17 m, or greater. Pressure of the water in the wellbore is maintained below the fracture pressure of the formation. In some embodiments, the water, or a portion of the water is removed from the wellbore, and a freeze well is placed in the formation.
FIG. 2 depicts an embodiment of freeze well 114. Freeze well 114 may include canister 116, inlet conduit 118, spacers 120, and wellcap 122. Spacers 120 may position inlet conduit 118 in canister 116 so that an annular space is formed between the canister and the conduit. Spacers 120 may promote turbulent flow of refrigerant in the annular space between inlet conduit 118 and canister 116, but the spacers may also cause a significant fluid pressure drop. Turbulent fluid flow in the annular space may be promoted by roughening the inner surface of canister 116, by roughening the outer surface of inlet conduit 118, and/or by having a small cross-sectional area annular space that allows for high refrigerant velocity in the annular space. In some embodiments, spacers are not used. Wellhead 123 may suspend canister 116 in wellbore 125.
Formation refrigerant may flow through cold side conduit 124 from a refrigeration unit to inlet conduit 118 of freeze well 114. The formation refrigerant may flow through an annular space between inlet conduit 118 and canister 116 to warm side conduit 126. Heat may transfer from the formation to canister 116 and from the canister to the formation refrigerant in the annular space. Inlet conduit 118 may be insulated to inhibit heat transfer to the formation refrigerant during passage of the formation refrigerant into freeze well 114. In an embodiment, inlet conduit 118 is a high density polyethylene tube. At cold temperatures, some polymers may exhibit a large amount of thermal contraction. For example, a 260 m initial length of polyethylene conduit subjected to a temperature of about -25 C may contract by 6 m or more. If a high density polyethylene conduit, or other polymer conduit, is used, the large thermal contraction of the material must be taken into account in determining the fmal depth of the freeze well.
For example, the freeze well may be drilled deeper than needed, and the conduit may be allowed to shrink back during use. In some embodiments, inlet conduit 118 is an insulated metal tube.
In some embodiments, the insulation may be a polymer coating, such as, but not limited to, polyvinylchloride, high density polyethylene, and/or polystyrene.
Freeze well 114 may be introduced into the formation using a coiled tubing rig. In an embodiment, canister 116 and inlet conduit 118 are wound on a single reel. The coiled tubing rig introduces the canister and inlet conduit Y'18'in'Eo Ifi-auf'e$iMu~rient, canister 116 is wound on a first reel and inlet conduit 118 is wound on a second reel. The coiled tubing rig introduces canister 116 into the formation.
Then, the coiled tubing rig is used to introduce inlet conduit 118 into the canister. In other embodiments, freeze well is assembled in sections at the wellbore site and introduced into the formation.
An insulated section of freeze well 114 may be placed adjacent to overburden 128. An uninsulated section of freeze well 114 may be placed adjacent to layer or layers 130 where a low temperature zone is to be formed. In some embodiments, uninsulated sections of the freeze wells may be positioned adjacent only to aquifers or other permeable portions of the formation that would allow fluid to flow into or out of the treatment area. Portions of the formation where uninsulated sections of the freeze wells are to be placed may be determined using analysis of cores and/or logging techniques.
Various types of refrigeration systems may be used to form a low temperature zone. Determination of an appropriate refrigeration system may be based on many factors, including, but not limited to: type of freeze well; a distance between adjacent freeze wells; refrigerant; time frame in which to form a low temperature zone; depth of the low temperature zone; temperature differential to which the refrigerant will be subjected; chemical and physical properties of the refrigerant; environmental concerns related to potential refrigerant releases, leaks, or spills;
economics; formation water flow in the forniation; composition and properties of formation water, including the salinity of the formation water; and various properties of the formation such as thermal conductivity, thermal diffusivity, and heat capacity.
A circulated fluid refrigeration system may utilize a liquid refrigerant (forma.tion refrigerant) that is circulated through freeze wells. Some of the desired properties for the formation refrigerant are: low working temperature, low viscosity at and near the working temperature, high density, high specific heat capacity, high thermal conductivity, low cost, low corrosiveness, and low toxicity. A low working temperature of the formation refrigerant allows a large low temperature zone to be established around a freeze well. The low working temperature of formation refrigerant should be about -20 C or lower. Formation refrigerants having low working temperatures of at least -60 C may include aqua ammonia, potassium formate solutions such as Dynalene HC-50 (Dynalene Heat Transfer Fluids (Whitehall, Pennsylvania, U.S.A.)) or FREEZIUM (Kemira Chemicals (Helsinki, Finland));
silicone heat transfer fluids such as Syltherm XLT (Dow Corning Corporation (Midland, Michigan, U.S.A.);
hydrocarbon refrigerants such as propylene; and chlorofluorocarbons such as R-22. Aqua annnonia is a solution of anunonia and water with a weight percent of ammonia between about 20% and about 40%. Aqua annnonia has several properties and characteristics that make use of aqua ammonia as the formation refrigerant desirable. Such properties and characteristics include, but are not limited to, a very low freezing point, a low viscosity, ready availability, and low cost.
Formation refrigerant that is capable of being chilled below a freezing temperature of aqueous formation fluid may be used to form the low temperature zone around the treatment area.
The following equation (the Sanger equation) may be used to model the time t, needed to form a frozen barrier of radius R around a freeze well having a surface temperature of Ts:
(1) t1= RzL' 21nR-l+c fvs 4k fvs r0 L, in which:
a; -1 L' - L a cvu vo 21nr a =RA.
r R
In these equations, kfis the thermal conductivity of the frozen material; cf and c,,, are the volumetric heat capacity of the frozen and unfrozen material, respectively; rm is the radius of the freeze well; vs is the temperature difference between the freeze well surface temperature Ts and the freezing point of water T0i v is the temperature difference between the ambient ground temperature Tg and the freezing point of water To, L is the volumetric latent heat of freezing of the formation; R is the radius at the frozen-unfrozen interface;
and RA is a radius at which there is no influence from the refrigeration pipe. The Sanger equation may provide a conservative estimate of the time needed to form a frozen barrier of radius R because the equation does not take into consideration superposition of cooling from other freeze wells. The temperature of the formation refrigerant is an adjustable variable that may significantly affect the spacing between freeze wells.
EQN. 1 implies that a large low temperature zone may be formed by using a refrigerant having an initial temperature that is very low. The use of formation refrigerant having an initial cold temperature of about -30 C or lower is desirable. Formation refrigerants having initial temperatures warmer than about -30 C may also be used, but such formation refrigerants require longer times for the low temperature zones produced by individual freeze wells to connect. In addition, such formation refrigerants may require the use of closer freeze well spacings and/or more freeze wells.
The physical properties of the material used to construct the freeze wells may be a factor in the determination of the coldest temperature of the formation refrigerant used to form the low temperature zone around the treatment area. Carbon steel may be used as a construction material of freeze wells. ASTM A333 grade 6 steel alloys and ASTM A333 grade 3 steel alloys may be used for low temperature applications. ASTM A333 grade 6 steel alloys typically contain little or no nickel and have a low working temperature limit of about -50 C. ASTM
A333 grade 3 steel alloys typically contain nickel and have a much colder low working temperature limit. The nickel in the ASTM A333 grade 3 alloy adds ductility at cold temperatures, but also significantly raises the cost of the metal. In some embodiments, the coldest temperature of the refrigerant is from about -35 C to about -55 C, from about -38 C to about -47 C, or from about -40 C to about -45 C to allow for the use of ASTM A333 grade 6 steel alloys for construction of canisters for freeze wells. Stainless steels, such as 304 stainless steel, may be used to form freeze wells, but the cost of stainless steel is typically much more than the cost of ASTM A333 grade 6 steel alloy.
In some embodiments, the metal used to form the canisters of the freeze wells may be provided as pipe. In some embodiments, the metal used to form the canisters of the freeze wells may be provided in sheet form. The sheet metal may be longitudinally welded to form pipe and/or coiled tubing.
Forming the canisters from sheet metal may improve the economics of the system by allowing for coiled tubing insulation and by reducing the equipment and manpower needed to form and install the canisters using pipe.
A refrigeration unit may be used to reduce the temperature of formation refrigerant to the low working temperature. In some embodiments, the refrigeration unit may utilize an ammonia vaporization cycle. Refrigeration units are available from Cool Man Inc. (Milwaukee, Wisconsin, U.S.A.), Gartner Refrigeration & Manufacturing (Minneapolis, Minnesota, U.S.A.), and other suppliers. In some embodiments, a cascading refrigeration system may ir" 'rlie &4liAd 'a"~'irst sAgO'%OA- Tinonia and a second stage of carbon dioxide. The circulating refrigerant through the freeze wells may be 30% by weight anunonia in water (aqua anunonia).
Alternatively, a single stage carbon dioxide refrigeration system may be used.
FIG. 3 depicts an embodiment of refrigeration system 132 used to cool formation refrigerant that forms a low temperature zone around treatment area 134. Refrigeration system 132 may include a high stage refrigeration system and a low stage refrigeration system arranged in a cascade relationship. The high stage refrigeration system and the low stage refrigeration system may utilize conventional vapor compression refrigeration cycles.
The high stage refrigeration system includes compressor 136, condenser 138, expansion valve 140, and heat exchanger 142. In some embodiments, the high stage refrigeration system uses ammonia as the refrigerant. The low stage refrigeration system includes compressor 144, heat exchanger 142, expansion valve 146, and heat exchanger 148. In some embodiments, the low stage refrigeration system uses carbon dioxide as the refrigerant. High stage refrigerant from high stage expansion valve 140 cools low stage refrigerant exiting low stage compressor 144 in heat exchanger 142.
Low stage refrigerant exiting low stage expansion valve 146 is used to cool formation refrigerant in heat exchanger 148. The formation refrigerant passes from heat exchanger 148 to storage vessel 150. Pump 152 transports formation refrigerant from storage vessel 150 to freeze wells 114 in formation 154. Refrigeration system 132 is operated so that the formation refrigerant from pump 152 is at the desired temperature. The desired temperature may be in the range from about -35 C to about -55 C.
Formation refrigerant passes from the freeze wells 114 to storage vessel 156.
Pump 158 is used to transport the formation refrigerant from storage vessel 156 to heat exchanger 148. In some embodiments, storage vessel 150 and storage vessel 156 are a single tank with a warm side for formation refrigerant returning from the freeze wells, and a cold side for formation refrigerant from heat exchanger 148.
Grout may be used in combination with freeze wells to provide a barrier for the in situ conversion process.
The grout fills cavities (vugs) in the formation and reduces the permeability of the formation. Grout may have better thermal conductivity than gas and/or formation fluid that fills cavities in the formation. Placing grout in the cavities may allow for faster low temperature zone formation. The grout forms a perpetual barrier in the formation that may strengthen the formation. The use of grout in unconsolidated or substantially unconsolidated formation material may allow for larger well spacing than is possible without the use of grout. The combination of grout and the low temperature zone formed by freeze wells may constitute a double barrier for environmental regulation purposes.
Grout may be introduced into the formation through freeze well wellbores. The grout may be allowed to set. The integrity of the grout wall may be checked. The integrity of the grout wall may be checked by logging techniques and/or by hydrostatic testing. If the permeability of a grouted section is too high, additional grout may be introduced into the formation through freeze well wellbores. After the permeability of the grouted section is sufficiently reduced, freeze wells may be installed in the freeze well wellbores.
;5 Grout may be injected into the formation at a pressure that is high, but below the fracture pressure of the formation. In some embodiments, grouting is performed in 16 m increments in the freeze wellbore. Larger or smaller increments may be used if desired. In some embodiments, grout is only applied to certain portions of the formation. For example, grout may be applied to the formation through the freeze wellbore only adjacent to aquifer zones and/or to relatively high permeability zones (for example, zones with a permeability greater than about 0.1 0 darcy). Applying grout to aquifers may inhibit migration of water from one aquifer to a different aquifer when an established low temperature zone thaws.
r R
In these equations, kfis the thermal conductivity of the frozen material; cf and c,,, are the volumetric heat capacity of the frozen and unfrozen material, respectively; rm is the radius of the freeze well; vs is the temperature difference between the freeze well surface temperature Ts and the freezing point of water T0i v is the temperature difference between the ambient ground temperature Tg and the freezing point of water To, L is the volumetric latent heat of freezing of the formation; R is the radius at the frozen-unfrozen interface;
and RA is a radius at which there is no influence from the refrigeration pipe. The Sanger equation may provide a conservative estimate of the time needed to form a frozen barrier of radius R because the equation does not take into consideration superposition of cooling from other freeze wells. The temperature of the formation refrigerant is an adjustable variable that may significantly affect the spacing between freeze wells.
EQN. 1 implies that a large low temperature zone may be formed by using a refrigerant having an initial temperature that is very low. The use of formation refrigerant having an initial cold temperature of about -30 C or lower is desirable. Formation refrigerants having initial temperatures warmer than about -30 C may also be used, but such formation refrigerants require longer times for the low temperature zones produced by individual freeze wells to connect. In addition, such formation refrigerants may require the use of closer freeze well spacings and/or more freeze wells.
The physical properties of the material used to construct the freeze wells may be a factor in the determination of the coldest temperature of the formation refrigerant used to form the low temperature zone around the treatment area. Carbon steel may be used as a construction material of freeze wells. ASTM A333 grade 6 steel alloys and ASTM A333 grade 3 steel alloys may be used for low temperature applications. ASTM A333 grade 6 steel alloys typically contain little or no nickel and have a low working temperature limit of about -50 C. ASTM
A333 grade 3 steel alloys typically contain nickel and have a much colder low working temperature limit. The nickel in the ASTM A333 grade 3 alloy adds ductility at cold temperatures, but also significantly raises the cost of the metal. In some embodiments, the coldest temperature of the refrigerant is from about -35 C to about -55 C, from about -38 C to about -47 C, or from about -40 C to about -45 C to allow for the use of ASTM A333 grade 6 steel alloys for construction of canisters for freeze wells. Stainless steels, such as 304 stainless steel, may be used to form freeze wells, but the cost of stainless steel is typically much more than the cost of ASTM A333 grade 6 steel alloy.
In some embodiments, the metal used to form the canisters of the freeze wells may be provided as pipe. In some embodiments, the metal used to form the canisters of the freeze wells may be provided in sheet form. The sheet metal may be longitudinally welded to form pipe and/or coiled tubing.
Forming the canisters from sheet metal may improve the economics of the system by allowing for coiled tubing insulation and by reducing the equipment and manpower needed to form and install the canisters using pipe.
A refrigeration unit may be used to reduce the temperature of formation refrigerant to the low working temperature. In some embodiments, the refrigeration unit may utilize an ammonia vaporization cycle. Refrigeration units are available from Cool Man Inc. (Milwaukee, Wisconsin, U.S.A.), Gartner Refrigeration & Manufacturing (Minneapolis, Minnesota, U.S.A.), and other suppliers. In some embodiments, a cascading refrigeration system may ir" 'rlie &4liAd 'a"~'irst sAgO'%OA- Tinonia and a second stage of carbon dioxide. The circulating refrigerant through the freeze wells may be 30% by weight anunonia in water (aqua anunonia).
Alternatively, a single stage carbon dioxide refrigeration system may be used.
FIG. 3 depicts an embodiment of refrigeration system 132 used to cool formation refrigerant that forms a low temperature zone around treatment area 134. Refrigeration system 132 may include a high stage refrigeration system and a low stage refrigeration system arranged in a cascade relationship. The high stage refrigeration system and the low stage refrigeration system may utilize conventional vapor compression refrigeration cycles.
The high stage refrigeration system includes compressor 136, condenser 138, expansion valve 140, and heat exchanger 142. In some embodiments, the high stage refrigeration system uses ammonia as the refrigerant. The low stage refrigeration system includes compressor 144, heat exchanger 142, expansion valve 146, and heat exchanger 148. In some embodiments, the low stage refrigeration system uses carbon dioxide as the refrigerant. High stage refrigerant from high stage expansion valve 140 cools low stage refrigerant exiting low stage compressor 144 in heat exchanger 142.
Low stage refrigerant exiting low stage expansion valve 146 is used to cool formation refrigerant in heat exchanger 148. The formation refrigerant passes from heat exchanger 148 to storage vessel 150. Pump 152 transports formation refrigerant from storage vessel 150 to freeze wells 114 in formation 154. Refrigeration system 132 is operated so that the formation refrigerant from pump 152 is at the desired temperature. The desired temperature may be in the range from about -35 C to about -55 C.
Formation refrigerant passes from the freeze wells 114 to storage vessel 156.
Pump 158 is used to transport the formation refrigerant from storage vessel 156 to heat exchanger 148. In some embodiments, storage vessel 150 and storage vessel 156 are a single tank with a warm side for formation refrigerant returning from the freeze wells, and a cold side for formation refrigerant from heat exchanger 148.
Grout may be used in combination with freeze wells to provide a barrier for the in situ conversion process.
The grout fills cavities (vugs) in the formation and reduces the permeability of the formation. Grout may have better thermal conductivity than gas and/or formation fluid that fills cavities in the formation. Placing grout in the cavities may allow for faster low temperature zone formation. The grout forms a perpetual barrier in the formation that may strengthen the formation. The use of grout in unconsolidated or substantially unconsolidated formation material may allow for larger well spacing than is possible without the use of grout. The combination of grout and the low temperature zone formed by freeze wells may constitute a double barrier for environmental regulation purposes.
Grout may be introduced into the formation through freeze well wellbores. The grout may be allowed to set. The integrity of the grout wall may be checked. The integrity of the grout wall may be checked by logging techniques and/or by hydrostatic testing. If the permeability of a grouted section is too high, additional grout may be introduced into the formation through freeze well wellbores. After the permeability of the grouted section is sufficiently reduced, freeze wells may be installed in the freeze well wellbores.
;5 Grout may be injected into the formation at a pressure that is high, but below the fracture pressure of the formation. In some embodiments, grouting is performed in 16 m increments in the freeze wellbore. Larger or smaller increments may be used if desired. In some embodiments, grout is only applied to certain portions of the formation. For example, grout may be applied to the formation through the freeze wellbore only adjacent to aquifer zones and/or to relatively high permeability zones (for example, zones with a permeability greater than about 0.1 0 darcy). Applying grout to aquifers may inhibit migration of water from one aquifer to a different aquifer when an established low temperature zone thaws.
=ar ~=!~ ~iu'~n z~n~tlon may be any type of grout including, but not limited to, fine cement, micro fine cement, sulfur, sulfur cement, viscous thermoplastics, or combinations thereof. Fine cement may be ASTM type 3 Portland cement. Fine cement may be less expensive than micro fine cement. In an embodiment, a freeze wellbore is formed in the formation. Selected portions of the freeze wellbore are grouted using fme cement. Then, micro fine cement is injected into the formation through the freeze wellbore. The fme cement may reduce the permeability_ down to about 10 millidarcy. The micro fme cement may further reduce the permeability to about 0.1 millidarcy.
After the grout is introduced into the formation, a freeze wellbore canister may be inserted into the formation. The process may be repeated for each freeze well that will be used to form the barrier.
.In some embodiments, fine cement is introduced into every other freeze wellbore. Micro fine cement is introduced into the remaining wellbores. For example, grout may be used in a formation with freeze wellbores set at about 5 m spacing. A first wellbore is drilled and fme cement is introduced into the formation through the wellbore.
A freeze well canister is positioned in the first wellbore. A second welibore is drilled 10 m away from the first wellbore. Fine cement is introduced into the formation through the second wellbore. A freeze well canister is positioned in the second wellbore. A third wellbore is drilled between the first wellbore and the second wellbore. In some embodiments, grout from the first and/or second wellbores may be detected in the cuttings of the third wellbore. Micro fme cement is introduced into the formation tbrough the third wellbore. A freeze wellbore canister is positioned in the third wellbore. The same procedure is used to form the remaining freeze wells that will form the barrier around the treatment area.
In some embodiments, heaters that heat hydrocarbons in the formation may be close to the low temperature zone established by freeze wells. In some embodiments, heaters may be may be 20 m, 10 m, 5 m or less from an edge of the low temperature zone established by freeze wells. In some embodiments, heat interceptor wells may be positioned between the low temperature zone and the heaters to reduce the heat load applied to the low temperature zone from the heated part of the formation. FIG. 4 depicts a schematic view of the well layout plan for heat sources 104, production wells 108, heat interceptor wells 160, and freeze wells 114 for a portion of an in situ conversion system enzbodiment. Heat interceptor wells 160 are positioned between heat sources 104 and freeze wells 114.
Some heat interceptor wells may be formed in the formation specifically for the purpose of reducing the heat load applied to the low temperature zone established by freeze wells.
Some heat interceptor wells may be heater welibores, monitor wellbores, production wellbores, dewatering wellbores or other type of wellbores that are converted for use as heat interceptor wells.
In some embodiments, heat interceptor wells may function as heat pipes to reduce the heat load applied to the low temperature zone. A liquid heat transfer fluid may be placed in the heat interceptor wellbores. The liquid may include, but is not limited to, water, alcohol, and/or alkanes. Heat supplied to the formation from the heaters may advance to the heat interceptor wellbores and vaporize the liquid heat transfer fluid in the heat interceptor wellbores. The resulting vapor may rise in the wellbores. Above the heated portion of the formation adjacent to the ;5 overburden, the vapor may condense and flow by gravity back to the area adjacent to the heated part of the formation. The heat absorbed by changing the phase of the liquid heat transfer fluid reduces the heat load applied to the low temperature zone. Using heat interceptor wells that function as heat pipes may be advantageous for formations with thick overburdens that are able to absorb the heat applied as the heat transfer fluid changes phase from vapor to liquid. The wellbore may include wicking material, packing to increase surface area adjacent to a 0 portion of the overburden, or other material to promote heat transfer to or from the formation and the heat transfer fluid.
1:._ ~ i'., ~..
mbo'Yms, a ~at transfer fluid is circulated through the heat interceptor wellbores in a closed loop system. A heat exchanger.reduces the temperature of the heat transfer fluid after the heat transfer fluid leaves the heat interceptor wellbores. Cooled heat transfer fluid is pumped through the heat interceptor wellbores. In some embodiments, the heat transfer fluid does not undergo a phase change during use. In some embodiments, the heat transfer fluid may change phases during use. The heat transfer fluid may be, but is not liniited to, water, alcohol, and/or glycol.
Further modifications and alternative embodiments of various aspects of the invention may be apparent to those skilled in the art in view of this description. Accordingly, this description is to be construed as illustrative only and is for the purpose of teaching those skilled in the art the general manner of carrying out the invention. It is to be understood that the forms of the invention shown and described herein are to be taken as the presently preferred embodiments. Elements and materials may be substituted for those illustrated and described herein, parts and processes nnay be reversed, and certain features of the invention may be utilized independently, all as would.be apparent to one skilled in the art after having the benefit of this description of the invention. Changes may be made in the elements described herein without departing from the spirit and scope of the invention as described in the following claims. In addifion, it is to be understood that features described herein independently may, in certain embodiments, be combined.
After the grout is introduced into the formation, a freeze wellbore canister may be inserted into the formation. The process may be repeated for each freeze well that will be used to form the barrier.
.In some embodiments, fine cement is introduced into every other freeze wellbore. Micro fine cement is introduced into the remaining wellbores. For example, grout may be used in a formation with freeze wellbores set at about 5 m spacing. A first wellbore is drilled and fme cement is introduced into the formation through the wellbore.
A freeze well canister is positioned in the first wellbore. A second welibore is drilled 10 m away from the first wellbore. Fine cement is introduced into the formation through the second wellbore. A freeze well canister is positioned in the second wellbore. A third wellbore is drilled between the first wellbore and the second wellbore. In some embodiments, grout from the first and/or second wellbores may be detected in the cuttings of the third wellbore. Micro fme cement is introduced into the formation tbrough the third wellbore. A freeze wellbore canister is positioned in the third wellbore. The same procedure is used to form the remaining freeze wells that will form the barrier around the treatment area.
In some embodiments, heaters that heat hydrocarbons in the formation may be close to the low temperature zone established by freeze wells. In some embodiments, heaters may be may be 20 m, 10 m, 5 m or less from an edge of the low temperature zone established by freeze wells. In some embodiments, heat interceptor wells may be positioned between the low temperature zone and the heaters to reduce the heat load applied to the low temperature zone from the heated part of the formation. FIG. 4 depicts a schematic view of the well layout plan for heat sources 104, production wells 108, heat interceptor wells 160, and freeze wells 114 for a portion of an in situ conversion system enzbodiment. Heat interceptor wells 160 are positioned between heat sources 104 and freeze wells 114.
Some heat interceptor wells may be formed in the formation specifically for the purpose of reducing the heat load applied to the low temperature zone established by freeze wells.
Some heat interceptor wells may be heater welibores, monitor wellbores, production wellbores, dewatering wellbores or other type of wellbores that are converted for use as heat interceptor wells.
In some embodiments, heat interceptor wells may function as heat pipes to reduce the heat load applied to the low temperature zone. A liquid heat transfer fluid may be placed in the heat interceptor wellbores. The liquid may include, but is not limited to, water, alcohol, and/or alkanes. Heat supplied to the formation from the heaters may advance to the heat interceptor wellbores and vaporize the liquid heat transfer fluid in the heat interceptor wellbores. The resulting vapor may rise in the wellbores. Above the heated portion of the formation adjacent to the ;5 overburden, the vapor may condense and flow by gravity back to the area adjacent to the heated part of the formation. The heat absorbed by changing the phase of the liquid heat transfer fluid reduces the heat load applied to the low temperature zone. Using heat interceptor wells that function as heat pipes may be advantageous for formations with thick overburdens that are able to absorb the heat applied as the heat transfer fluid changes phase from vapor to liquid. The wellbore may include wicking material, packing to increase surface area adjacent to a 0 portion of the overburden, or other material to promote heat transfer to or from the formation and the heat transfer fluid.
1:._ ~ i'., ~..
mbo'Yms, a ~at transfer fluid is circulated through the heat interceptor wellbores in a closed loop system. A heat exchanger.reduces the temperature of the heat transfer fluid after the heat transfer fluid leaves the heat interceptor wellbores. Cooled heat transfer fluid is pumped through the heat interceptor wellbores. In some embodiments, the heat transfer fluid does not undergo a phase change during use. In some embodiments, the heat transfer fluid may change phases during use. The heat transfer fluid may be, but is not liniited to, water, alcohol, and/or glycol.
Further modifications and alternative embodiments of various aspects of the invention may be apparent to those skilled in the art in view of this description. Accordingly, this description is to be construed as illustrative only and is for the purpose of teaching those skilled in the art the general manner of carrying out the invention. It is to be understood that the forms of the invention shown and described herein are to be taken as the presently preferred embodiments. Elements and materials may be substituted for those illustrated and described herein, parts and processes nnay be reversed, and certain features of the invention may be utilized independently, all as would.be apparent to one skilled in the art after having the benefit of this description of the invention. Changes may be made in the elements described herein without departing from the spirit and scope of the invention as described in the following claims. In addifion, it is to be understood that features described herein independently may, in certain embodiments, be combined.
Claims (20)
1. A system for forming a low temperature zone around at least a portion of a subsurface treatment area, comprising:
a plurality of freeze wells, wherein at least one freeze well positioned in the ground comprises a carbon steel canister;
heat transfer fluid; and a refrigeration system configured to supply the heat transfer fluid to the freeze wells, wherein the refrigeration system is configured to cool the heat transfer fluid to a temperature that allows the heat transfer fluid provided to a first freeze well to be in a range from -35 °C to -55 °C.
a plurality of freeze wells, wherein at least one freeze well positioned in the ground comprises a carbon steel canister;
heat transfer fluid; and a refrigeration system configured to supply the heat transfer fluid to the freeze wells, wherein the refrigeration system is configured to cool the heat transfer fluid to a temperature that allows the heat transfer fluid provided to a first freeze well to be in a range from -35 °C to -55 °C.
2. The system as claimed claim 1, wherein the heat transfer fluid comprises aqua ammonia.
3. The system as claimed in any of claims 1 or 2, where the freeze well with a carbon steel canister comprises a polymer inlet conduit.
4. The system as claimed in any of claims 1-4, wherein grout is placed in the formation through at least one wellbore in which a freeze well canister is placed.
5. The system as claimed in any of claims 1-4, further comprising at least one heat interceptor well placed between a freeze well and heater wells in the subsurface treatment area.
6. A method of forming and maintaining a low temperature zone as claimed in any of claims 1-5, comprising:
reducing the temperature of the heat transfer fluid with the refrigeration system;
circulating the heat transfer fluid through freeze well canisters; and returning the heat transfer fluid to the refrigeration system.
reducing the temperature of the heat transfer fluid with the refrigeration system;
circulating the heat transfer fluid through freeze well canisters; and returning the heat transfer fluid to the refrigeration system.
7. The method as claimed in claim 6, wherein at least one freeze well canister is longitudinally welded.
8. The method as claimed in any of claims 6 or 7, further comprising storing at least a part of the heat transfer fluid in a storage tank prior to and/or after reducing the temperature with the refrigeration system.
9. The method as claimed in any of claims 6-8, wherein the refrigeration system comprises a cascade refrigeration system.
10. The method as claimed in any of claims 6-9, wherein the initial temperature of the heat transfer fluid supplied to the first carbon steel freeze well canister is in a range from -38 °C to -50 °C.
11. The method as claimed in any of claims 6-9, wherein the initial temperature of the heat transfer fluid supplied to the first carbon steel freeze well canister is in a range from -40 °C to -45 °C.
12. The method as claimed in any of claims 6-11, further comprising reducing the heat applied to the low temperature zone by placing heat interceptor wells between heat sources in the treatment area and the freeze well canisters.
13. The method as claimed in any of claims 6-12, further comprising heating at least a portion of the subsurface treatment area.
14. The method as claimed in any of claims 6-13, further comprising producing a composition comprising hydrocarbons from the subsurface treatment area.
15. The method as claimed in claim 14, further comprising treating at least a portion of the composition to make transportation fuel.
16. A method of establishing a barrier around at least a portion of a subsurface treatment area, comprising:
introducing grout into the information through wellbores to reduce permeability of the formation near the wellbores;
placing freeze wells in two or more of the wellbores; and forming a low temperature barrier by circulating a heat transfer fluid through the freeze wells.
introducing grout into the information through wellbores to reduce permeability of the formation near the wellbores;
placing freeze wells in two or more of the wellbores; and forming a low temperature barrier by circulating a heat transfer fluid through the freeze wells.
17. The method of claim 16, further comprising checking the sufficiency of the permeability reduction prior to placing the freeze wells in the wellbores.
18. A composition comprising hydrocarbons produced from a subsurface formation, the subsurface formation including the system as claimed in any of claims 1-6 or including a low temperature zone or barrier formed using the methods as claimed in any of claims 6-17.
19. A transportation fuel comprising hydrocarbons made from the composition as claimed in claim 18.
20. A system for forming a low temperature zone around at least a portion of a subsurface treatment area, comprising:
a plurality of freeze wells, wherein at least one freeze well positioned in the ground comprises carbon steel a carbon steel canister;
heat transfer fluid; and a refrigeration system configured to supply the heat transfer fluid to the freeze wells, wherein the refrigeration system is configured to cool the heat transfer fluid.
a plurality of freeze wells, wherein at least one freeze well positioned in the ground comprises carbon steel a carbon steel canister;
heat transfer fluid; and a refrigeration system configured to supply the heat transfer fluid to the freeze wells, wherein the refrigeration system is configured to cool the heat transfer fluid.
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| PCT/US2006/015104 WO2006116095A1 (en) | 2005-04-22 | 2006-04-21 | Low temperature barriers for use with in situ processes |
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| CA2606217A Expired - Fee Related CA2606217C (en) | 2005-04-22 | 2006-04-21 | Subsurface connection methods for subsurface heaters |
| CA2606216A Expired - Fee Related CA2606216C (en) | 2005-04-22 | 2006-04-21 | Temperature limited heater utilizing non-ferromagnetic conductor |
| CA2605720A Expired - Fee Related CA2605720C (en) | 2005-04-22 | 2006-04-21 | Double barrier system for an in situ conversion process |
| CA2606176A Expired - Fee Related CA2606176C (en) | 2005-04-22 | 2006-04-21 | Insulated conductor temperature limited heater for subsurface heating coupled in a three-phase wye configuration |
| CA2606218A Expired - Fee Related CA2606218C (en) | 2005-04-22 | 2006-04-21 | In situ conversion process systems utilizing wellbores in at least two regions of a formation |
| CA2606181A Expired - Fee Related CA2606181C (en) | 2005-04-22 | 2006-04-21 | Low temperature barriers for use with in situ processes |
| CA2605729A Expired - Fee Related CA2605729C (en) | 2005-04-22 | 2006-04-21 | In situ conversion process utilizing a closed loop heating system |
| CA2606210A Expired - Fee Related CA2606210C (en) | 2005-04-22 | 2006-04-21 | Grouped exposed metal heaters |
| CA2606165A Expired - Fee Related CA2606165C (en) | 2005-04-22 | 2006-04-21 | Low temperature monitoring system for subsurface barriers |
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| CA2606217A Expired - Fee Related CA2606217C (en) | 2005-04-22 | 2006-04-21 | Subsurface connection methods for subsurface heaters |
| CA2606216A Expired - Fee Related CA2606216C (en) | 2005-04-22 | 2006-04-21 | Temperature limited heater utilizing non-ferromagnetic conductor |
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| CA2606176A Expired - Fee Related CA2606176C (en) | 2005-04-22 | 2006-04-21 | Insulated conductor temperature limited heater for subsurface heating coupled in a three-phase wye configuration |
| CA2606218A Expired - Fee Related CA2606218C (en) | 2005-04-22 | 2006-04-21 | In situ conversion process systems utilizing wellbores in at least two regions of a formation |
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| CA2606210A Expired - Fee Related CA2606210C (en) | 2005-04-22 | 2006-04-21 | Grouped exposed metal heaters |
| CA2606165A Expired - Fee Related CA2606165C (en) | 2005-04-22 | 2006-04-21 | Low temperature monitoring system for subsurface barriers |
| CA2606295A Expired - Fee Related CA2606295C (en) | 2005-04-22 | 2006-04-21 | Varying properties along lengths of temperature limited heaters |
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