CA2556367A1 - Well bore servicing fluids comprising thermally activated viscosification compounds and methods of using the same - Google Patents
Well bore servicing fluids comprising thermally activated viscosification compounds and methods of using the same Download PDFInfo
- Publication number
- CA2556367A1 CA2556367A1 CA002556367A CA2556367A CA2556367A1 CA 2556367 A1 CA2556367 A1 CA 2556367A1 CA 002556367 A CA002556367 A CA 002556367A CA 2556367 A CA2556367 A CA 2556367A CA 2556367 A1 CA2556367 A1 CA 2556367A1
- Authority
- CA
- Canada
- Prior art keywords
- servicing fluid
- well bore
- fluid
- servicing
- thermally activated
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 239000012530 fluid Substances 0.000 title claims abstract 67
- 238000000034 method Methods 0.000 title claims abstract 22
- 150000001875 compounds Chemical class 0.000 title claims abstract 19
- 229920000642 polymer Polymers 0.000 claims abstract 12
- 125000004432 carbon atom Chemical group C* 0.000 claims abstract 3
- 239000004568 cement Substances 0.000 claims abstract 3
- 238000005553 drilling Methods 0.000 claims abstract 3
- 230000002209 hydrophobic effect Effects 0.000 claims abstract 3
- 238000012856 packing Methods 0.000 claims abstract 3
- 239000007787 solid Substances 0.000 claims abstract 3
- 125000001424 substituent group Chemical group 0.000 claims abstract 3
- -1 poly(ethyleneglycol-(DL-lactic acid)-ethyleneglycol) Polymers 0.000 claims 11
- 229920001577 copolymer Polymers 0.000 claims 6
- 229910017053 inorganic salt Inorganic materials 0.000 claims 4
- 150000003839 salts Chemical class 0.000 claims 4
- 238000005520 cutting process Methods 0.000 claims 3
- RTZKZFJDLAIYFH-UHFFFAOYSA-N ether Substances CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims 3
- 230000002441 reversible effect Effects 0.000 claims 3
- 230000015572 biosynthetic process Effects 0.000 claims 2
- 239000002563 ionic surfactant Substances 0.000 claims 2
- QNILTEGFHQSKFF-UHFFFAOYSA-N n-propan-2-ylprop-2-enamide Chemical compound CC(C)NC(=O)C=C QNILTEGFHQSKFF-UHFFFAOYSA-N 0.000 claims 2
- 239000002736 nonionic surfactant Substances 0.000 claims 2
- 229920001495 poly(sodium acrylate) polymer Polymers 0.000 claims 2
- 239000002002 slurry Substances 0.000 claims 2
- PQUXFUBNSYCQAL-UHFFFAOYSA-N 1-(2,3-difluorophenyl)ethanone Chemical compound CC(=O)C1=CC=CC(F)=C1F PQUXFUBNSYCQAL-UHFFFAOYSA-N 0.000 claims 1
- DZSVIVLGBJKQAP-UHFFFAOYSA-N 1-(2-methyl-5-propan-2-ylcyclohex-2-en-1-yl)propan-1-one Chemical compound CCC(=O)C1CC(C(C)C)CC=C1C DZSVIVLGBJKQAP-UHFFFAOYSA-N 0.000 claims 1
- JWYVGKFDLWWQJX-UHFFFAOYSA-N 1-ethenylazepan-2-one Chemical compound C=CN1CCCCCC1=O JWYVGKFDLWWQJX-UHFFFAOYSA-N 0.000 claims 1
- SMZOUWXMTYCWNB-UHFFFAOYSA-N 2-(2-methoxy-5-methylphenyl)ethanamine Chemical compound COC1=CC=C(C)C=C1CCN SMZOUWXMTYCWNB-UHFFFAOYSA-N 0.000 claims 1
- NIXOWILDQLNWCW-UHFFFAOYSA-N 2-Propenoic acid Natural products OC(=O)C=C NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 claims 1
- DMKKMGYBLFUGTO-UHFFFAOYSA-N 2-methyloxirane;oxirane Chemical compound C1CO1.C1CO1.CC1CO1 DMKKMGYBLFUGTO-UHFFFAOYSA-N 0.000 claims 1
- JTHZUSWLNCPZLX-UHFFFAOYSA-N 6-fluoro-3-methyl-2h-indazole Chemical compound FC1=CC=C2C(C)=NNC2=C1 JTHZUSWLNCPZLX-UHFFFAOYSA-N 0.000 claims 1
- 229920002153 Hydroxypropyl cellulose Polymers 0.000 claims 1
- 229920003171 Poly (ethylene oxide) Polymers 0.000 claims 1
- 125000004183 alkoxy alkyl group Chemical group 0.000 claims 1
- 125000005250 alkyl acrylate group Chemical group 0.000 claims 1
- 229920013820 alkyl cellulose Polymers 0.000 claims 1
- 150000003863 ammonium salts Chemical class 0.000 claims 1
- 230000003247 decreasing effect Effects 0.000 claims 1
- 239000001863 hydroxypropyl cellulose Substances 0.000 claims 1
- 235000010977 hydroxypropyl cellulose Nutrition 0.000 claims 1
- 239000001866 hydroxypropyl methyl cellulose Substances 0.000 claims 1
- 229920003088 hydroxypropyl methyl cellulose Polymers 0.000 claims 1
- 235000010979 hydroxypropyl methyl cellulose Nutrition 0.000 claims 1
- UFVKGYZPFZQRLF-UHFFFAOYSA-N hydroxypropyl methyl cellulose Chemical compound OC1C(O)C(OC)OC(CO)C1OC1C(O)C(O)C(OC2C(C(O)C(OC3C(C(O)C(O)C(CO)O3)O)C(CO)O2)O)C(CO)O1 UFVKGYZPFZQRLF-UHFFFAOYSA-N 0.000 claims 1
- 230000002427 irreversible effect Effects 0.000 claims 1
- YLGXILFCIXHCMC-JHGZEJCSSA-N methyl cellulose Chemical compound COC1C(OC)C(OC)C(COC)O[C@H]1O[C@H]1C(OC)C(OC)C(OC)OC1COC YLGXILFCIXHCMC-JHGZEJCSSA-N 0.000 claims 1
- 239000000178 monomer Substances 0.000 claims 1
- YLGYACDQVQQZSW-UHFFFAOYSA-N n,n-dimethylprop-2-enamide Chemical class CN(C)C(=O)C=C YLGYACDQVQQZSW-UHFFFAOYSA-N 0.000 claims 1
- XFHJDMUEHUHAJW-UHFFFAOYSA-N n-tert-butylprop-2-enamide Chemical compound CC(C)(C)NC(=O)C=C XFHJDMUEHUHAJW-UHFFFAOYSA-N 0.000 claims 1
- XAEFZNCEHLXOMS-UHFFFAOYSA-M potassium benzoate Chemical compound [K+].[O-]C(=O)C1=CC=CC=C1 XAEFZNCEHLXOMS-UHFFFAOYSA-M 0.000 claims 1
- 229940047670 sodium acrylate Drugs 0.000 claims 1
- 159000000000 sodium salts Chemical class 0.000 claims 1
- 229920001897 terpolymer Polymers 0.000 claims 1
- PFTXCWNJFWPRTO-UHFFFAOYSA-N trimethyl-[3-(prop-2-enoylamino)propyl]azanium;iodide Chemical compound [I-].C[N+](C)(C)CCCNC(=O)C=C PFTXCWNJFWPRTO-UHFFFAOYSA-N 0.000 claims 1
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
- C09K8/02—Well-drilling compositions
- C09K8/03—Specific additives for general use in well-drilling compositions
- C09K8/035—Organic additives
-
- 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
-
- 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
- C09K8/70—Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
- C09K8/706—Encapsulated breakers
Abstract
Well bore servicing fluids are provided that include a thermally activated viscosification compound. Further, methods of servicing a well bore are provided that include displacing such a servicing fluid into the well bore, wherein a viscosity of the servicing fluid increases as it passes down the well bore due to its temperature increasing. Thus, the viscosity of the servicing fluid is effective to suspend solids therein when the servicing fluid is in the well bore. The servicing fluid may be, for example, a cement slung, a drilling fluid, a gravel packing fluid, a fracturing fluid, a completion fluid, or a work-over fluid. In an embodiment, the thermally activated viscosification compound includes at least one water-soluble hydrophobically modified polymer comprising a hydrophobic substituent having from about 1 to about 22 carbon atoms.
Claims (36)
1. ~A method of servicing a well bore, comprising: displacing a servicing fluid comprising a thermally activated viscosification compound into the well bore, wherein a viscosity of the servicing fluid increases as it passes down the well bore due to its temperature increasing.
2. ~The method of claim 1, wherein the thermally activated viscosification compound forms a thermally reversible gel as it passes down the well bore due to its temperature increasing.
3. ~The method of claim 1, wherein the thermally activated viscosification compound forms a thermally irreversible gel as it passes down the well bore due to its temperature increasing.
4. ~The method of claim 1, wherein the servicing fluid comprises a cement slurry, a drilling fluid, a gravel packing fluid, a fracturing fluid, a completion fluid, a work-over fluid, or combinations thereof.
5. ~The method of claim 1, wherein the thermally activated viscosification compound comprises a water-soluble hydrophobically modified polymer comprising a hydrophobic substituent having from about 1 to about 22 carbon atoms.
6. ~The method of claim 5, wherein the hydrophobically modified polymer is non-ionic.
7. ~The method of claim 6, wherein the non-ionic hydrophobically modified polymer comprises alkyl hydroxyl alkylcellulose, methyl cellulose ether, hydroxypropyl methyl cellulose ether, hydroxypropyl cellulose ether, copolymers of N-alkylacrylamides and hydrophilic comonomers, copolymers of N,N-dimethylacrylamides and alkoxyalkyl or alkyl acrylates, ethyleneoxide-propyleneoxide-ethyleneoxide tri-block polymers, poly(ethyleneglycol-(DL-lactic acid)-ethyleneglycol) triblock copolymersor, or combinations thereof.
8. ~The method of claim 6, wherein the servicing fluid further comprises an ionic surfactant, an inorganic salt, or combinations thereof.
9. ~The method of claim 5, wherein the hydrophobically modified polymer is ionic.
10. ~The method of claim 9, wherein the ionic hydrophobically modified polymer comprises copolymers of N-alkylacrylamides and ionic monomers, copolymers of stearylacrylate and acrylic acid, terpolymers of N-isopropylacrylamide, trimethyl acrylamidopropyl ammonium iodide, and 3-dimethyl- (methacryloxyethyl) ammonium propane sulfonate, copolymers of N-tertiarybutylacrylamide or N-isopropylacrylamide and 2-acrylamide-2-methyl propane sulfonic acid, poly(ethyleneoxide)-block-poly(propyleneoxide)-block-poly(ethyleneoxide) grafted with poly(sodium acrylate);
hydrophobically modified poly(sodium acrylate), a copolymer of N-vinylcaprolactam and sodium acrylate, or combinations thereof.
hydrophobically modified poly(sodium acrylate), a copolymer of N-vinylcaprolactam and sodium acrylate, or combinations thereof.
11. The method of claim 9, wherein the servicing fluid further comprises a non-ionic surfactant, an inorganic salt, or combinations thereof.
12. The method of claim 4, wherein a viscosity of the servicing fluid is effective to suspend solids therein when the servicing fluid is in the well bore.
13. The method of claim 4, wherein the servicing fluid further comprises an encapsulated salt that is released downhole to reduce a temperature of the servicing fluid and thereby reduce a viscosity of the servicing fluid.
14. The method of claim 13, wherein the servicing fluid comprises a fracturing fluid, and wherein the encapsulated salt is released after using the servicing fluid to fracture the subterranean formation.
15. The method of claim 1, further comprising flowing the servicing fluid back to the surface of the earth.
16. The method of claim 15, wherein the viscosity of the servicing fluid is effective to suspend drill cuttings therein as the servicing fluid flows to the surface of the earth.
17. The method of claim 16, further comprising allowing the viscosity of the servicing fluid to decrease at the surface due to its temperature decreasing, thereby causing the drill cuttings to settle.
18. The method of claim 1, wherein the thermally activated viscosification compound comprises a chemically crosslinked gel-forming compound, a physically crosslinked gel-forming compound, or combinations thereof.
19. The method of claim 1, wherein the thermally activated viscosification compound comprises a linear polymer that is capable of being physically crosslinked.
20. The method of claim 1, wherein an amount of the thermally activated viscosification compound present in the servicing fluid ranges from about 0.1% to about 5% by total weight of the servicing fluid.
21. A well bore servicing fluid comprising a thermally activated viscosification compound.
22. The well bore servicing fluid of claim 21, wherein the servicing fluid comprises a cement slurry, a drilling fluid, a gravel packing fluid, a fracturing fluid, or combinations thereof.
23. The well bore servicing fluid of claim 21, wherein the thermally activated viscosification compound comprises a water-soluble, hydrophobically modified polymer comprising a hydrophobic substituent having from about 1 to about 22 carbon atoms.
24. The well bore servicing fluid of claim 23, wherein the hydrophobically modified polymer is non-ionic.
25. The well bore servicing fluid of claim 24, wherein the servicing fluid further comprises an ionic surfactant, an inorganic salt, or combinations thereof.
26. The well bore servicing fluid of claim 23, wherein the hydrophobically modified polymer is ionic.
27. The well bore servicing fluid of claim 26, wherein the servicing fluid further comprises a non-ionic surfactant, an inorganic salt, or combinations thereof.
28. The well bore servicing fluid of claim 21, wherein a viscosity of the servicing fluid is effective to suspend solids therein when the servicing fluid is in the well bore.
29. The well bore servicing fluid of claim 21, wherein the servicing fluid further comprises an encapsulated salt that is capable of being released downhole for reducing a temperature of the servicing fluid and thereby reducing a viscosity of the servicing fluid.
30. The well bore servicing fluid of claim 29, wherein the encapsulated salt comprises an ammonium salt, a sodium salt, a potassium salt, or combinations thereof.
31. The well bore servicing fluid of claim 21, wherein a viscosity of the servicing fluid is effective to suspend drill cuttings therein when the servicing fluid is pumped from the subterranean formation to near the surface of the earth.
32. The well bore servicing fluid of claim 21, wherein the thermally activated viscosification compound is capable of forming a chemically crosslinked gel, a physically crosslinked gel, or combinations thereof.
33. The well bore servicing fluid of claim 21, wherein the thermally activated viscosification compound comprises a linear polymer that capable of forming a physically crosslinked gel.
34. The well bore servicing fluid of claim 21, wherein the thermally activated viscosification compound is capable of forming a thermally reversible gel.
35. The well bore servicing fluid of claim 21, wherein an amount of the thermally activated viscosification compound present in the servicing fluid ranges from about 0.1% to about 5% by total weight of the servicing fluid.
36. A well bore servicing fluid comprising a thermally activated viscosification compound that is capable of forming a thermally reversible gel.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US10/780,314 | 2004-02-17 | ||
| US10/780,314 US7351681B2 (en) | 2004-02-17 | 2004-02-17 | Well bore servicing fluids comprising thermally activated viscosification compounds and methods of using the same |
| PCT/GB2004/005336 WO2005080748A1 (en) | 2004-02-17 | 2004-12-17 | Well bore servicing fluids comprising thermally activated viscosification compounds and methods of using the same |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2556367A1 true CA2556367A1 (en) | 2005-09-01 |
| CA2556367C CA2556367C (en) | 2010-04-06 |
Family
ID=34838566
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2556367A Expired - Fee Related CA2556367C (en) | 2004-02-17 | 2004-12-17 | Well bore servicing fluids comprising thermally activated viscosification compounds and methods of using the same |
Country Status (6)
| Country | Link |
|---|---|
| US (2) | US7351681B2 (en) |
| EP (1) | EP1714003B1 (en) |
| AR (1) | AR047650A1 (en) |
| CA (1) | CA2556367C (en) |
| NO (1) | NO341418B1 (en) |
| WO (1) | WO2005080748A1 (en) |
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- 2004-12-17 EP EP04806138.6A patent/EP1714003B1/en not_active Expired - Fee Related
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| AR047650A1 (en) | 2006-02-01 |
| US7686084B2 (en) | 2010-03-30 |
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| WO2005080748A1 (en) | 2005-09-01 |
| EP1714003B1 (en) | 2016-08-31 |
| US20080121395A1 (en) | 2008-05-29 |
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| NO20064173L (en) | 2006-11-17 |
| US20050178546A1 (en) | 2005-08-18 |
| EP1714003A1 (en) | 2006-10-25 |
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