CA2408764A1 - Well service composition comprising a fracturing fluid and a gas hydratecontroller and the method of using the composition - Google Patents

Well service composition comprising a fracturing fluid and a gas hydratecontroller and the method of using the composition Download PDF

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Publication number
CA2408764A1
CA2408764A1 CA002408764A CA2408764A CA2408764A1 CA 2408764 A1 CA2408764 A1 CA 2408764A1 CA 002408764 A CA002408764 A CA 002408764A CA 2408764 A CA2408764 A CA 2408764A CA 2408764 A1 CA2408764 A1 CA 2408764A1
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Canada
Prior art keywords
polymer
composition
fracturing fluid
controller
gas hydrate
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Granted
Application number
CA002408764A
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French (fr)
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CA2408764C (en
Inventor
Marek K. Pakulski
Jeffrey C. Dawson
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BJ Services Co Canada
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Individual
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Expired - Fee Related legal-status Critical Current

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Classifications

    • 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
    • C09K8/66—Compositions based on water or polar solvents
    • C09K8/68—Compositions based on water or polar solvents containing organic compounds
    • C09K8/685—Compositions based on water or polar solvents containing organic compounds containing cross-linking agents
    • 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
    • C09K8/66—Compositions based on water or polar solvents
    • C09K8/665—Compositions based on water or polar solvents containing inorganic compounds
    • 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
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/22—Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers
    • 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
    • Y10S507/903—Crosslinked resin or polymer
    • 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

Abstract

A well service fluid composition comprises a fracturing fluid and a gas hydrate inhibitor. Preferably, the gas hydrate inhibitor does not affect the function of the fracturing fluid and is present in an amount sufficient to control and/or minimize the formation of gas hydrates. The well service fluid composition is useful in hydraulic fracturing in which the composition is injected into a subterranean formation under sufficient pressure to initiate and propagate a fracture in the formation. The fracturing fluid may be subsequently recovered when the fracturing operation is completed.

Claims (60)

Claims:
1. A well service composition, comprising:
a fracturing fluid; and a gas hydrate controller, wherein the gas hydrate controller is in an amount effective to control the formation of gas hydrates.
2. The composition of claim 1, wherein:
the fracturing fluid comprises water; and the gas hydrate controller is present at about 0.01% by weight to about 5% by weight of the water.
3. The composition of claim 1, wherein:
the fracturing fluid comprises water; and the gas hydrate controller is present at about 0.05% by weight to about 1% by weight of the water.
4. The composition of claim 1, wherein:
the fracturing fluid comprises water, and the gas hydrate controller is present at about 0.03%.by weight to about 0.75%
by weight of the water.
5. The composition of claim 1, wherein the fracturing fluid further comprises a proppant.
6. The composition of claim 1, wherein the fracturing fluid further comprises a breaking agent.
7. The composition of claim 1, wherein the fracturing fluid further comprises a clay stabilizer.
8. The composition of claim 1, wherein fracturing fluid further comprises KCI
or a quaternary ammonium salt.
9. The composition of claim 1, wherein the fracturing fluid further comprises a pH
buffering agent.
10. The composition of claim 1, wherein the fracturing fluid has a pH in the range of about 3.2 to about 11Ø
11. The composition of claim 1, wherein the fracturing fluid has a pH in the range of about 9.8 to about 10.5.
12. The composition of claim 1, wherein the gas hydrate controller is a polyglycolpolyamine.
13. The composition of claim 1, wherein the gas hydrate controller is a polyglycolpolyamine polycondensation product of a reaction between a polyoxyalkylene glycol and a polyamine.
l4. The composition of claim 1, wherein the gas hydrate controller is a polyglycolpolyamine having the structure:

R7R'NCHR"CH2(OCH2CR")a N(R')2 wherein R7 is H, CH3, or -[R'NCHR"CH2(OCH2CHR")n NR']m-R';
wherein R' is H or CH3;
wherein R" is H or CH3;
wherein n is 1 to 99; and wherein m is 0 to 99.
15. The composition of claim 1, wherein the fracturing fluid comprises:
an aqueous fluid;
a water-soluble polymer; and a cross-linking agent capable of increasing the viscosity of the fracturing fluid by crosslinking the polymer in the aqueous fluid.
16. The composition of claim 15, wherein the polymer and aqueous fluid are present at a ratio of up to about 20 pounds polymer per 1,000 gallons aqueous fluid.
17. The composition of claim 15, wherein the polymer and aqueous fluid are present at a ratio of up to about 15 pounds polymer per 1,000 gallons aqueous fluid
18. The composition of claim 15, wherein the polymer and aqueous fluid are present - at a ratio of at least about 20 pounds polymer per 1,000 gallons aqueous fluid.
19. The composition of claim 15, wherein the polymer and aqueous fluid are present at a ratio of about 40 pounds polymer per 1,000 gallons aqueous fluid to about pounds polymer per 1,000 gallons aqueous fluid.
20. The composition of claim 15, wherein the polymer is a polysaccharide.
21. The composition of claim 15, wherein the polymer is guar, carboxymethyl guar, carboxyethyl guar, hydroxypropyl guar, hydroxyethyl guar, carboxymethylhydroxypropyl guar, salts thereof, or mixtures thereof.
22. The composition of claim 15, wherein the cross-linking agent is boric acid, organoborate, boric oxide, alkali metal borate, alkaline earth natal borate, or a mixture thereof.
23. The composition of claim 15, wherein the polymer is a guar polymer or a derivative thereof and the cross-linking agent is a borate cross-linking agent.
24. The composition of claim 15, wherein the gas hydrate controller further comprises a second polymer capable of controlling or minimizing the formation of gas hydrates.
25. The composition of claim 24, wherein the second polymer is a homopolymer or copolymer of N, N-dialkylamineoethylmethacrylates or a mixture thereof.
26, The composition of claim 24, wherein the second polymer is a homopolymer or copolymer of N- vinyl-N-alkyl amides or a mixture thereof.
27. The composition of claim 24, wherein the second polymer is a homopolymer or copolymer of N- vinyl lactams or a mixture thereof.
28. The composition of claim 24, wherein the second polymer is a homopolymer or copolymer of N- methyl-N-vinylacetamide /lactams or a mixture thereof.
29. The composition of claim 24, wherein the second polymer is a homopolymer or copolymer of N- acyl substituted polyalkeneimines or a mixture thereof.
30. The composition of claim 24, wherein the second polymer is a homopolymer or a copolymer of N,N-dialkylaminoethylmethacrylates, N-vinyl-N-alkyl amides, and N-vinyl lactams, N-methyl- N-vinylacetamide /lactam copolymer, an N-acyl substituted polyalkeneimines or a mixture thereof.
31. A method of fracturing a subterranean formation, the method comprising;
providing a well service composition comprising a fracturing fluid and a gas hydrate controller; and injecting the well service composition into a borehole to contact at least a portion of the formation with the well service composition under a sufficient pressure to fracture the formation; wherein the gas hydrate controller is present in the composition in a concentration effective to control the formation of gas hydrates.
32. The method of claim 31, wherein:
the fracturing fluid comprises water; and the gas hydrate controller is present at about 0.01% by weight to about 5% by weight of the water.
33. The method of claim 31, wherein:
the fracturing fluid comprises water; and the gas hydrate controller is present at about 0.05% by weight to about 1% by weight of the water.
34. The method of claim 31, wherein:
the fracturing fluid comprises water; and the gas hydrate controller is present at about 0.03% by weight to about 0.75%
by weight of the water.
35. The method of claim 31, wherein the fracturing fluid further comprises a proppant.
36. The method of claim 31, wherein the fracturing fluid further comprises a breaking agent.
37. The method of claim 31, wherein the fracturing fluid further comprises a clay stabilizer.
38. The method of claim 31, wherein fracturing fluid further comprises KCI or a quaternary ammonium salt.
39. The method of claim 31, wherein the fracturing fluid further comprises a pH
buffering agent.
40. The method of claim 31, wherein the fracturing fluid has a pH in the range of about 3.2 to about 11Ø
41. The method of claim 31, wherein the fracturing fluid has a pH in the range of about 9.8 to about 10.5.
42. The method of claim 31, wherein the gas hydrate controller is a polyglycolpolyamine.
43. The method of claim 31, wherein the gas hydrate controller is a polyglycolpolyamine polycondensation product of a reaction between a polyoxyalkylene glycol and a polyamine.
44. The method of claim 31, wherein the gas hydrate controller is a ployglycolpolyamine having the structure:
R7R'NCHR"CH2(OCH2CR")n N(R')2 wherein R7 is H, CH3, or -[R'NCHR"CH2(OCH2CHR")n R']m-R';
wherein R' is H or CH3;
wherein R" is H or CH3;
wherein n is 1 to 99; and wherein m is 0 to 99.
45. The method of claim 31, wherein the fracturing fluid comprises:
an aqueous fluid;
a water-soluble polymer, and a cross-linking agent capable of increasing the viscosity of the fracturing fluid by crosslinking the polymer in the aqueous fluid.
46. The method of claim 45, wherein the polymer and aqueous fluid are present at a ratio of up to about 20 pounds polymer per 1,000 gallons aqueous fluid.
47. The method of claim 45, wherein the polymer and aqueous fluid are present at a ratio of up to about 15 pounds polymer per 1,000 gallons aqueous fluid.
48. The method of claim 45. wherein the polymer and aqueous fluid are present at a ratio of at least about 20 pounds polymer per 1,000 gallons aqueous fluid.
49. The method of claim 45, wherein the polymer and aqueous fluid are present at a ratio of about 40 pounds polymer per 1,000 gallons aqueous fluid to about 60 pounds polymer per 1,000 gallons aqueous fluid.
50. The method of claim 45, wherein the polymer is a polysaccharide.
51. The method of claim 45, wherein the polymer is guar, carboxymethyl guar, carboxyethyl guar, hydroxypropyl guar, hydroxyethyl guar, carboxymethylhydroxypropyl guar, salts thereof, or mixtures thereof.
52. The method of claim 45, wherein the cross-lining agent is boric acid, organoborate, boric oxide, alkali metal bore, alkaline earth metal borate, or a mixture thereof.
53. The method of claim 45, wherein the polymer is a guar polymer or a derivative thereof and the cross-linking agent is a cross-linking agent.
54. The method of claim 45, wherein the gas hydrate controller further comprises a second polymer capable of controlling or minimizing the formation of gas hydrates.
55. The method of claim 54, wherein the second polymer is a homopolymer or copolymer of N,N-dialkylamineoethylmethacrylates or a mixture thereof.
56. The method of claim 54, wherein the second polymer is a homopolymer or copolymer of N-vinyl-N-alkyl amides or a mixture thereof.
57. The method of claim 54, wherein the second polymer is a homopolymer or copolymer of N-vinyl lactams or a mixture thereof.
58. The method of claim 54, wherein the second polymer is a homopolymer or copolymer of N- methyl-N-vinylacetamide/lactams or a mixture thereof.
59. The method of claim 54, wherein the second polymer is a homopolymer or copolymer of N-acyl substituted polyalkeneimines or a mixture thereof.
60. The method of claim 54, wherein the second polymer is a homopolymer or a copolymer of N,N-dialkylaminoethylmethacrylates, N-vinyl-N-alkyl amides, and N-vinyl lactate, N methyl- N-vinylacetamide /lactam copolymer, an N-acyl substituted polyalkeneimines or a mixture thereof.
CA002408764A 2000-05-15 2001-05-15 Well service composition comprising a fracturing fluid and a gas hydratecontroller and the method of using the composition Expired - Fee Related CA2408764C (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US20415300P 2000-05-15 2000-05-15
US60/204,153 2000-05-15
PCT/US2001/015517 WO2001088334A2 (en) 2000-05-15 2001-05-15 Well service composition and method

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CA2408764A1 true CA2408764A1 (en) 2001-11-22
CA2408764C CA2408764C (en) 2010-02-02

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US (2) US6756345B2 (en)
AU (1) AU2001261566A1 (en)
BR (1) BR0110771A (en)
CA (1) CA2408764C (en)
NO (1) NO20025451L (en)
WO (1) WO2001088334A2 (en)

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