CA2640359A1 - Method for hydraulic fracturing of subterranean formation - Google Patents

Method for hydraulic fracturing of subterranean formation Download PDF

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Publication number
CA2640359A1
CA2640359A1 CA002640359A CA2640359A CA2640359A1 CA 2640359 A1 CA2640359 A1 CA 2640359A1 CA 002640359 A CA002640359 A CA 002640359A CA 2640359 A CA2640359 A CA 2640359A CA 2640359 A1 CA2640359 A1 CA 2640359A1
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CA
Canada
Prior art keywords
stated
fracturing fluid
proppant
fracture
particles
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Granted
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CA002640359A
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French (fr)
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CA2640359C (en
Inventor
Dean Willberg
Matthew Miller
Ivan Vitalievich Kosarev
Marc Thiercelin
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Schlumberger Canada Ltd
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Individual
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    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/62—Compositions for forming crevices or fractures
    • C09K8/70—Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
    • C09K8/706—Encapsulated breakers
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/80—Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
    • 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
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
    • Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10S507/00—Earth boring, well treating, and oil field chemistry
    • Y10S507/922—Fracture fluid
    • Y10S507/924—Fracture fluid with specified propping feature

Abstract

The invention provides economically effective methods for hydraulic fracturing a subterranean formation that ensure improvement of the hydraulic fractureconductivity because of forming strong proppant clusters uniformly placed in the fracture throughout its length. One of these methods comprises:
a first stage that involves injection into a borehole of fracturing fluid containing thickeners to create a fracture in the formation; and a second stage that involves periodic introduction of proppant into the injected fracturing fluid to supply the proppant into a created fracture, to form proppant clusters within the fracture to prevent fracture closure and channels for flowing formation fluids between the clusters, wherein the second stage or its sub-stages involve additional introduction of either a reinforcing or consolidation material or both, thus increasing the strength of the proppant clusters formed into the fracture fluid.

Claims (70)

1. A method for hydraulic fracturing of subterranean formation comprising: a first stage that involves injection into a borehole of fracturing fluid containing thickeners to create a fracture in the formation; and a second stage that involves periodic introduction of proppant into the injected fracturing fluid to supply the proppant into a created fracture, to form proppant clusters within the fracture to prevent fracture closure and channels for flowing formation fluids between the clusters, wherein the second stage or its sub-stages involve additional introduction of either a reinforcing or consolidation material or both, thus increasing the strength of the proppant clusters formed into the fracture fluid.
2. The method as stated in claim 1, wherein the reinforcing or consolidation material or both are introduced either into the propping sub-stages, as the proppant is introduced into the fracturing fluid, or continuously throughout both the propping and carrying sub-stages.
3. The method as stated in claim 1 or claim 2, wherein the reinforcing or consolidating material or both represent: organic, inorganic, or organic and inorganic fibers with an adhesive coating alone or an adhesive coating coated by a layer of non-adhesive substance dissolvable in the fracturing fluid during its passage through the fracture; metallic particles of spherical or elongated shape; plates of organic or inorganic substances, ceramics, metals or metal alloys with the ratio between any two of the three dimensions greater than 5 to 1.
4. The method as stated all of claims 1-3, wherein the second stage further involves introduction of an agent into the fracturing fluid, this agent increasing the proppant transport capability of the fluid.
5. The method as stated in claim 4, wherein the agent is a material with elongated particles with the ratio between any two of the three dimensions greater than to 1.
6. The method as stated in claim 5, wherein the material with elongated particles is introduced when the proppant is not introduced into the fracturing fluid, or continuously.
7. The method as stated in claim 6, wherein the elongated particles are fibers made from naturally occurring or synthetic organic materials, or glass, ceramic, carbon, inorganic or metallic fibers.
8. The method as stated in claim 7, characterized by fibers made on the basis of polylactic acid, polyglycolic acid, polyethylterephthalate (PET), copolymers of these polyesters and polyvinylalcohol.
9. The method as stated in claim 7, characterized by fibers coated by, or made of, a material that becomes adhesive at formation temperatures.
10. The method as stated in claim 7, characterized by fibers made of adhesive material coated by a non-adhesive substance that dissolves in the fracturing fluid as it passes through the fracture.
11. The method as stated in claim 5, characterized by a weight concentration of the material in the fracturing fluid of 0.1-10 %.
12. The method as stated in claim 5, characterized by materials more than 2 mm long with diameters of 3-200 µm.
13. The method as stated in all of claims 1-12, characterized by the volume of injection of the proppant-containing fracturing fluid being less than the volume of injection of the fluid containing no proppant, to create smaller proppant clusters and larger channels between them for formation fluids to pass.
14. The method as stated in all of claims 1-13, characterized by the proppant comprising a mixture of material fractions with different particle diameters, a diameter ratio of particles in each fraction, and a relative amount of each fraction being selected, to minimize the resulting porosity of the proppant cluster or islands.
15. The method as stated in all of claims 1-14, characterized by particles of the proppant having a resinous or adhesive coating alone, or a resinous or adhesive coating coated by a layer of non-adhesive substance dissolvable in the fracturing fluid as it passes through the fracture.
16. The method as stated in all of claims 1-15, characterized by a third stage that involves continuous introduction of a proppant into the fracturing fluid, the proppant having an essentially uniform size of particles.
17. The method as stated in claim 16, characterized by the third stage further involving continuous introduction of a reinforcing material, consolidation material, or both, into the fracturing fluid.
18. The method as stated in claim 16 or claim 17, characterized by the third stage further involving continuous introduction of a material into the fracturing fluid, the material having elongated particles that increase the proppant transport capability of the fluid.
19. A method for hydraulic fracturing of subterranean formation comprising: a first stage that involves injection of fracturing fluid into a borehole, the fluid containing thickeners to create a fracture in the formation; and a second stage that involves introduction of proppant into the injected fracturing fluid to prevent closure of the created fracture, and further, involving periodic introduction of an agent into the fracturing fluid to provide formation of proppant clusters in the created fracture and channels for flowing formation fluids.
20. The method as stated in claim 19, characterized in that, to form proppant clusters the agent reacts with the fracturing fluid after a lapse of time from the moment it's introduced into the fracturing fluid, that moment varied to provide the reaction of the agent with the fracturing fluid in different places in the created fracture, and formation of the proppant clusters in these places.
21. The method as stated in claim 20, including the step of varying the time period using one of the following mechanisms: variation of the agent's chemical composition; encapsulation of the agent in granules protected by shells destroyed during the time period by dissolving the shells in the fracturing fluid, or by erosive destruction of them by collisions with otller agent particles and a fracture surface, or crushing them with the fracture faces at fracture closure; encapsulation of the agent in semi-permeable shells that swell and rupture in the fracturing fluid; encapsulation of the agent in a semi-permeable membrane or porous shell for its slow diffusion through it;
encapsulation of the agent into a shell capable of dissolving or washing it out.
22. The method as stated in claim 20, including the step of varying the time period using one of the following mechanisms: varying the agent's chemical composition; encapsulating the agent in granules of porous material that are destroyed during the time period by dissolving the shells in fracturing fluid, or by erosive destruction of the granules by collision with other agent particles and a fracture surface, or by crushing the granules at closure of the fracture walls, or slow leaching of the reactive chemicals out of the granule.
23. The method as stated in claims 19-22, characterized by the agent representing additives providing drastic and significant local decrease in viscosity of the fracturing fluid and settlement of the proppant therein.
24. The method as stated in claim 23, characterized by additives that are fracturing fluid breakers that react therein in different places in the fracture.
25. The method as stated in claim 24, characterized by a breaker with particles coated by shells of various thicknesses that dissolve in the fracturing fluid and release the breaker for its reaction with the fracturing fluid in various places of the fracture.
26. The method as stated in claim 24 or claim 25, characterized in that the breaker of the fracture fluid is an oxidant that reacts with the fracturing fluid and results in polymer chain ruptures of the fracturing fluid.
27. The method as stated in claim 26, characterized by a catalyst introduced into the fracturing fluid to increase the reaction rate of an oxidant already dissolved or dispersed within the fracturing fluid.
28. The method as stated in claim 23, characterized by additives that can destroy a crosslink site, occupy a crosslink site, or sequester the crosslinker species of a crosslinked fracturing fluid.
29. The method as stated in claim 28, characterized by additives coated by shells of various thicknesses that dissolve in the fracturing fluid and release the additives in various places of the fracture.
30. The method as stated in claim 28 or claim 29, characterized by additives represent by polylactic acid, polyglycolic acid, polyvinylalcohols, sorbitol, gluconates, EDTA, NTA or phosphates.
31. The method as stated in claim 23, characterized by additives which are explosives, propellants, reactive metals, or any other reactive materials that result in localized heating of fracturing fluid and are encapsulated in the shells that are destroyed when entering the fracture and release the additives in various places of the fracture.
32. The method as stated in claim 19, characterized by the agent representing additives that reduce the mobility of proppant particles.
33. The method as stated in claim 32, characterized by additives which are fiber bundles encapsulated in shells, or bound together by slowly releasing sizing agents, whose dissolution in the fracturing fluid provides hydration or dispersion of fibers and an increase in their concentration in the fracturing fluid.
34. The method as stated in claim 32, characterized by additives that are materials that return to their initial shape when heated to a certain temperature.
35. The method as stated in claim 34, characterized in that the material represents lengths of fibers twisted into balls that straighten or increase their volume when heated.
36. The method as stated in claim 32, characterized by additives of materials with high absorbing capacity.
37. The method as stated in claim 36, characterized by particles of a material with high absorbing capacity physically or chemically delayed by either a temporary shell, temporary crosslinks, or temporary chemical treatments, that delay the hydration and volumetric expansion of the absorbent material until it reaches its desired location in the fracture, wherein the absorbent is activated by dissolution of the delay agent(s), temperature, abrasion of the material, or a combination of these three.
38. The method as stated in claim 32, characterized by additives that are granules, fibers, or plates whose surface becomes adhesive at formation temperatures.
39. The method as stated in claim 38, characterized by the granules, fibers, or plates having an adhesive surface coated by a layer of a non-adhesive substance dissolvable in the fracturing fluid.
40. The method as stated in any one of claims 19-39, characterized by the second stage involving further introduction of a material into the fracturing fluid continuously or simultaneously with the agent, the material having elongated particles whose length much exceeds their diameter and increases the proppant transport ability of the fluid.
41. The method as stated in claim 40, characterized by the material having elongated particles involving naturally occurring organic, synthetic organic, glass, ceramic, carbon, inorganic, and metallic fibers.
42. The method as stated in claim 41, characterized by fibers made on the basis of polymers that can undergo hydrolysis into water-soluble oligomers, or monomers.
Specific examples include polylactic acid, polyglycolic acid, polyethylterephthate (PET), and copolymers thereof.
43. The method as stated in claim 41, characterized by fibers made on the basis of polymers that slowly dissolve, or whose dissolution depends on temperature.
Specific examples include fibers based on polyvinyl alcohol.
44. The method as stated in claim 41, characterized by fibers coated with, or made of, a material that becomes adhesive at formation temperatures.
45. The method as stated in claim 41, characterized by fibers made of a material that is adhesive and coated with a non-adhesive substance that dissolves in the fracturing fluid.
46. The method as stated in claim 40, characterized by the concentration of a material having elongated particles of 0.1-30% by weight of the fluid.
47. The method as stated in claim 40, characterized by the particles of the material having an aspect ratio greater than 5:1.
48. The method as stated all of claims 19-47, characterized by the second stage further involving introduction of a reinforcing or consolidation material, or both, into the fracturing fluid continuously or simultaneously with the agent.
49. The method as stated in claim 48, characterized by a reinforcing material of:
organic, inorganic, or organic and inorganic fibers, having an adhesive coating alone or an adhesive coating coated by a layer of non-adhesive substance dissolvable in the fracturing fluid as it passes through the fracture; metallic particles having a spherical or an elongated shape; plates of organic or inorganic substances, ceramics, metals or metal alloys, having an aspect ratio greater than 5:1.
50. The method as stated in all of claims 19-49, characterized by the proppant comprising a mixture of material fractions having different diameters of their particles, a diameter ratio of particles in each fraction, and a relative amount of each fraction being selected to minimize the resulting porosity of the proppant.
51. The method as stated all of claims 19-50, characterized by particles of the proppant having an adhesive coating alone or an adhesive coating coated by a layer of non-adhesive substance dissolvable in the fracturing fluid as it passes through the fracture.
52. The method as stated all of claims 19-5 1, characterized by a third stage that involves continuous introduction of a proppant into the fracturing fluid, the proppant having essentially uniform particle size.
53. The method as stated in claim 52, characterized by the third stage further involving continuous introduction of a reinforcing material into the fracturing fluid.
54. The method as stated in claim 52 or claim 53, characterized by the third stage further involving continuous introduction of a material into the fracturing fluid, the material having elongated particles that increase the proppant transport ability of the fluid.
55. A method for hydraulic fracturing a subterranean formation comprising: a first stage that involves injection of a fracturing fluid into a borehole, the fluid containing thickeners to create a fracture of the formation; a second stage that involves continuous introduction of a proppant into the injected fracturing fluid to supply the proppant into a created fracture to prevent its closure; and a third stage that involves injection of a lower-viscosity, in comparison with fracturing, fluid into the fracturing fluid, the lower-viscosity fluid, owing to the difference in viscosity compared to the fracturing fluid, penetrating into the fracturing fluid in the form of intrusions that divide the proppant into discrete clusters to form channels between them through which formation fluids to pass.
56. The method of claim 55, characterized by the second stage further involving introduction of a material into the fracturing fluid continuously or simultaneously with the agent, the material having elongated particles whose lengths exceeds their diameters by an aspect ratio of greater than 5:1 and increase the proppant transport ability of the fluid.
57. The method as stated in claim 56, characterized by the material having elongated particles involving naturally occurring organic, inorganic, synthetic organic, glass, ceramic, carbon, and metallic fibers.
58. The method as stated in claim 57, characterized by fibers made on the basis of polymers that can undergo hydrolysis into water-soluble oligimers, or monomers, polylactic acid, polyglycolic acid, polyethylterethate (PET), and copolymers thereof.
59. The method as stated in claim 58, characterized by fibers made on the basis of polymers that slowly dissolve, or whose dissolution is very dependant on temperature. Specific examples include fibers based on polyvinyl alcohol.
60. The method as stated in claim 57, characterized by fibers coated by, or made of, a material that becomes adhesive at the formation temperatures.
61. The method as stated in claim 57, characterized by fibers made of a material that is adhesive and coated by a non-adhesive substance that dissolves in the fracturing fluid as it passes through the fracture.
62. The method as stated in claim 56, characterized by a weight concentration of the material in the fracturing fluid of 0.1-30 %.
63. The method as stated in claim 56, characterized by the particles of the material having an aspect ratio greater than 5:1.
64. The method as stated all of claims 55-63, characterized by the second stage further involving introduction of a reinforcing material into the fracturing fluid continuously or simultaneously with the agent.
65. The method as stated in claim 55, characterized by a reinforcing material of:
organic, inorganic, or organic and inorganic fibers, having an adhesive coating alone or an adhesive coating coated by a layer of non-adhesive substance dissolvable in the fracturing fluid as it passes through the fracture; metallic particles having a spherical or an elongated shape; plates of organic or inorganic substances, ceramics, metals or metal alloys, with a ratio between any two of the three dimensions greater than 5 to 1.
66. The method as stated all of claims 55-65, characterized by the proppant comprising a mixture of material fractions having different diameters of particles, a diameter ratio of particles in each fraction and a relative amount of each fraction selected so as to minimize the resulting porosity of the proppant.
67. The method as stated in any one of claims 55-66, characterized by particles of the proppant having an adhesive coating alone or an adhesive coating covered by a layer of a non-adhesive substance that is soluble in the fracturing fluid as it passes through the fracture.
68. The method as stated in any one of claims 55-67, characterized by a fourth stage that involves continuous introduction of a proppant into the fracturing fluid, the proppant having essentially uniform particle size.
69. The method as stated in claim 68, characterized by the fourth stage further involving continuous introduction of a reinforcing material into the fracturing fluid.
70. The method as stated in claim 67 or claim 68, characterized by the fourth stage further involving continuous introduction of a material into the fracturing fluid, the material having elongated particles that increase the proppant transport ability of the fluid.
CA2640359A 2006-01-27 2006-01-27 Method for hydraulic fracturing of subterranean formation Active CA2640359C (en)

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PCT/RU2006/000026 WO2007086771A1 (en) 2006-01-27 2006-01-27 Method for hydraulic fracturing of subterranean formation

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EP (1) EP1977079A1 (en)
CN (1) CN101371005B (en)
AU (1) AU2006336479B2 (en)
CA (1) CA2640359C (en)
DE (1) DE06769529T1 (en)
EG (1) EG26640A (en)
RU (1) RU2404359C2 (en)
WO (1) WO2007086771A1 (en)

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