US20120318514A1 - Methods of treating a subterranean formation containing hydrocarbons - Google Patents
Methods of treating a subterranean formation containing hydrocarbons Download PDFInfo
- Publication number
- US20120318514A1 US20120318514A1 US13/352,064 US201213352064A US2012318514A1 US 20120318514 A1 US20120318514 A1 US 20120318514A1 US 201213352064 A US201213352064 A US 201213352064A US 2012318514 A1 US2012318514 A1 US 2012318514A1
- Authority
- US
- United States
- Prior art keywords
- surface energy
- gelling agent
- subterranean formation
- reducing agent
- energy reducing
- 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.)
- Abandoned
Links
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 86
- 238000000034 method Methods 0.000 title claims abstract description 31
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 26
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 21
- 239000003349 gelling agent Substances 0.000 claims abstract description 81
- 239000012530 fluid Substances 0.000 claims abstract description 56
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 52
- 239000003915 liquefied petroleum gas Substances 0.000 claims description 28
- 239000002736 nonionic surfactant Substances 0.000 claims description 15
- 239000003945 anionic surfactant Substances 0.000 claims description 13
- 239000004094 surface-active agent Substances 0.000 claims description 12
- 239000003093 cationic surfactant Substances 0.000 claims description 8
- 239000002888 zwitterionic surfactant Substances 0.000 claims description 7
- 239000011248 coating agent Substances 0.000 claims description 6
- 238000000576 coating method Methods 0.000 claims description 6
- 239000002563 ionic surfactant Substances 0.000 claims description 6
- 238000005755 formation reaction Methods 0.000 description 70
- OFBQJSOFQDEBGM-UHFFFAOYSA-N Pentane Chemical compound CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 26
- -1 breakers Substances 0.000 description 21
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 18
- 125000000962 organic group Chemical group 0.000 description 15
- 239000000499 gel Substances 0.000 description 14
- 239000000126 substance Substances 0.000 description 13
- 125000004432 carbon atom Chemical group C* 0.000 description 12
- 239000002585 base Substances 0.000 description 11
- 239000007788 liquid Substances 0.000 description 10
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 10
- 229910019142 PO4 Inorganic materials 0.000 description 9
- 150000004703 alkoxides Chemical class 0.000 description 9
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 9
- 235000021317 phosphate Nutrition 0.000 description 9
- 239000001294 propane Substances 0.000 description 9
- 239000001273 butane Substances 0.000 description 8
- 239000007787 solid Substances 0.000 description 8
- 229910052783 alkali metal Inorganic materials 0.000 description 7
- 150000001340 alkali metals Chemical class 0.000 description 7
- 150000007942 carboxylates Chemical class 0.000 description 7
- 239000000463 material Substances 0.000 description 7
- 239000010452 phosphate Substances 0.000 description 7
- 238000011282 treatment Methods 0.000 description 7
- LYCAIKOWRPUZTN-UHFFFAOYSA-N ethylene glycol Natural products OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 description 6
- 208000003173 lipoprotein glomerulopathy Diseases 0.000 description 6
- 239000000203 mixture Substances 0.000 description 6
- 150000001412 amines Chemical class 0.000 description 5
- NBIIXXVUZAFLBC-UHFFFAOYSA-K phosphate Chemical compound [O-]P([O-])([O-])=O NBIIXXVUZAFLBC-UHFFFAOYSA-K 0.000 description 5
- 239000000243 solution Substances 0.000 description 5
- 238000012360 testing method Methods 0.000 description 5
- 229920003171 Poly (ethylene oxide) Polymers 0.000 description 4
- 230000001419 dependent effect Effects 0.000 description 4
- BXWNKGSJHAJOGX-UHFFFAOYSA-N hexadecan-1-ol Chemical compound CCCCCCCCCCCCCCCCO BXWNKGSJHAJOGX-UHFFFAOYSA-N 0.000 description 4
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- 238000004519 manufacturing process Methods 0.000 description 4
- 229910052698 phosphorus Inorganic materials 0.000 description 4
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- 150000003871 sulfonates Chemical class 0.000 description 4
- 239000004215 Carbon black (E152) Substances 0.000 description 3
- LZZYPRNAOMGNLH-UHFFFAOYSA-M Cetrimonium bromide Chemical compound [Br-].CCCCCCCCCCCCCCCC[N+](C)(C)C LZZYPRNAOMGNLH-UHFFFAOYSA-M 0.000 description 3
- OAICVXFJPJFONN-UHFFFAOYSA-N Phosphorus Chemical compound [P] OAICVXFJPJFONN-UHFFFAOYSA-N 0.000 description 3
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 description 3
- 239000012190 activator Substances 0.000 description 3
- 229960000686 benzalkonium chloride Drugs 0.000 description 3
- CADWTSSKOVRVJC-UHFFFAOYSA-N benzyl(dimethyl)azanium;chloride Chemical compound [Cl-].C[NH+](C)CC1=CC=CC=C1 CADWTSSKOVRVJC-UHFFFAOYSA-N 0.000 description 3
- 150000005690 diesters Chemical class 0.000 description 3
- 229910052739 hydrogen Inorganic materials 0.000 description 3
- 239000001257 hydrogen Substances 0.000 description 3
- 229910052744 lithium Inorganic materials 0.000 description 3
- GLDOVTGHNKAZLK-UHFFFAOYSA-N octadecan-1-ol Chemical compound CCCCCCCCCCCCCCCCCCO GLDOVTGHNKAZLK-UHFFFAOYSA-N 0.000 description 3
- 150000003141 primary amines Chemical class 0.000 description 3
- 150000003335 secondary amines Chemical class 0.000 description 3
- 235000019333 sodium laurylsulphate Nutrition 0.000 description 3
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 description 3
- 238000009736 wetting Methods 0.000 description 3
- YFSUTJLHUFNCNZ-UHFFFAOYSA-M 1,1,2,2,3,3,4,4,5,5,6,6,7,7,8,8,8-heptadecafluorooctane-1-sulfonate Chemical compound [O-]S(=O)(=O)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)F YFSUTJLHUFNCNZ-UHFFFAOYSA-M 0.000 description 2
- UMCMPZBLKLEWAF-BCTGSCMUSA-N 3-[(3-cholamidopropyl)dimethylammonio]propane-1-sulfonate Chemical compound C([C@H]1C[C@H]2O)[C@H](O)CC[C@]1(C)[C@@H]1[C@@H]2[C@@H]2CC[C@H]([C@@H](CCC(=O)NCCC[N+](C)(C)CCCS([O-])(=O)=O)C)[C@@]2(C)[C@@H](O)C1 UMCMPZBLKLEWAF-BCTGSCMUSA-N 0.000 description 2
- ZOXJGFHDIHLPTG-UHFFFAOYSA-N Boron Chemical compound [B] ZOXJGFHDIHLPTG-UHFFFAOYSA-N 0.000 description 2
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 2
- PEDCQBHIVMGVHV-UHFFFAOYSA-N Glycerol Natural products OCC(O)CO PEDCQBHIVMGVHV-UHFFFAOYSA-N 0.000 description 2
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical group [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 2
- WHXSMMKQMYFTQS-UHFFFAOYSA-N Lithium Chemical compound [Li] WHXSMMKQMYFTQS-UHFFFAOYSA-N 0.000 description 2
- MZRVEZGGRBJDDB-UHFFFAOYSA-N N-Butyllithium Chemical compound [Li]CCCC MZRVEZGGRBJDDB-UHFFFAOYSA-N 0.000 description 2
- NBIIXXVUZAFLBC-UHFFFAOYSA-N Phosphoric acid Chemical compound OP(O)(O)=O NBIIXXVUZAFLBC-UHFFFAOYSA-N 0.000 description 2
- 125000000217 alkyl group Chemical group 0.000 description 2
- 229910052782 aluminium Inorganic materials 0.000 description 2
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 description 2
- 125000000129 anionic group Chemical group 0.000 description 2
- 150000001450 anions Chemical class 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 229960001950 benzethonium chloride Drugs 0.000 description 2
- UREZNYTWGJKWBI-UHFFFAOYSA-M benzethonium chloride Chemical compound [Cl-].C1=CC(C(C)(C)CC(C)(C)C)=CC=C1OCCOCC[N+](C)(C)CC1=CC=CC=C1 UREZNYTWGJKWBI-UHFFFAOYSA-M 0.000 description 2
- 229910052796 boron Inorganic materials 0.000 description 2
- 229960000541 cetyl alcohol Drugs 0.000 description 2
- 229960001927 cetylpyridinium chloride Drugs 0.000 description 2
- NFCRBQADEGXVDL-UHFFFAOYSA-M cetylpyridinium chloride monohydrate Chemical compound O.[Cl-].CCCCCCCCCCCCCCCC[N+]1=CC=CC=C1 NFCRBQADEGXVDL-UHFFFAOYSA-M 0.000 description 2
- WOWHHFRSBJGXCM-UHFFFAOYSA-M cetyltrimethylammonium chloride Chemical compound [Cl-].CCCCCCCCCCCCCCCC[N+](C)(C)C WOWHHFRSBJGXCM-UHFFFAOYSA-M 0.000 description 2
- 239000003153 chemical reaction reagent Substances 0.000 description 2
- 150000001875 compounds Chemical class 0.000 description 2
- 238000009792 diffusion process Methods 0.000 description 2
- PSLWZOIUBRXAQW-UHFFFAOYSA-M dimethyl(dioctadecyl)azanium;bromide Chemical compound [Br-].CCCCCCCCCCCCCCCCCC[N+](C)(C)CCCCCCCCCCCCCCCCCC PSLWZOIUBRXAQW-UHFFFAOYSA-M 0.000 description 2
- LQZZUXJYWNFBMV-UHFFFAOYSA-N dodecan-1-ol Chemical compound CCCCCCCCCCCCO LQZZUXJYWNFBMV-UHFFFAOYSA-N 0.000 description 2
- 150000002170 ethers Chemical class 0.000 description 2
- 239000007789 gas Substances 0.000 description 2
- 150000004677 hydrates Chemical class 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- NNPPMTNAJDCUHE-UHFFFAOYSA-N isobutane Chemical compound CC(C)C NNPPMTNAJDCUHE-UHFFFAOYSA-N 0.000 description 2
- 150000003013 phosphoric acid derivatives Chemical class 0.000 description 2
- 229920000642 polymer Polymers 0.000 description 2
- 229920001451 polypropylene glycol Polymers 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 150000003512 tertiary amines Chemical class 0.000 description 2
- ALSTYHKOOCGGFT-KTKRTIGZSA-N (9Z)-octadecen-1-ol Chemical compound CCCCCCCC\C=C/CCCCCCCCO ALSTYHKOOCGGFT-KTKRTIGZSA-N 0.000 description 1
- JGTNAGYHADQMCM-UHFFFAOYSA-M 1,1,2,2,3,3,4,4,4-nonafluorobutane-1-sulfonate Chemical compound [O-]S(=O)(=O)C(F)(F)C(F)(F)C(F)(F)C(F)(F)F JGTNAGYHADQMCM-UHFFFAOYSA-M 0.000 description 1
- HNSDLXPSAYFUHK-UHFFFAOYSA-N 1,4-bis(2-ethylhexyl) sulfosuccinate Chemical class CCCCC(CC)COC(=O)CC(S(O)(=O)=O)C(=O)OCC(CC)CCCC HNSDLXPSAYFUHK-UHFFFAOYSA-N 0.000 description 1
- IIZPXYDJLKNOIY-JXPKJXOSSA-N 1-palmitoyl-2-arachidonoyl-sn-glycero-3-phosphocholine Chemical compound CCCCCCCCCCCCCCCC(=O)OC[C@H](COP([O-])(=O)OCC[N+](C)(C)C)OC(=O)CCC\C=C/C\C=C/C\C=C/C\C=C/CCCCC IIZPXYDJLKNOIY-JXPKJXOSSA-N 0.000 description 1
- SNGREZUHAYWORS-UHFFFAOYSA-M 2,2,3,3,4,4,5,5,6,6,7,7,8,8,8-pentadecafluorooctanoate Chemical compound [O-]C(=O)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)F SNGREZUHAYWORS-UHFFFAOYSA-M 0.000 description 1
- UZUFPBIDKMEQEQ-UHFFFAOYSA-M 2,2,3,3,4,4,5,5,6,6,7,7,8,8,9,9,9-heptadecafluorononanoate Chemical compound [O-]C(=O)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)F UZUFPBIDKMEQEQ-UHFFFAOYSA-M 0.000 description 1
- IXOCGRPBILEGOX-UHFFFAOYSA-N 3-[3-(dodecanoylamino)propyl-dimethylazaniumyl]-2-hydroxypropane-1-sulfonate Chemical compound CCCCCCCCCCCC(=O)NCCC[N+](C)(C)CC(O)CS([O-])(=O)=O IXOCGRPBILEGOX-UHFFFAOYSA-N 0.000 description 1
- CDOUZKKFHVEKRI-UHFFFAOYSA-N 3-bromo-n-[(prop-2-enoylamino)methyl]propanamide Chemical compound BrCCC(=O)NCNC(=O)C=C CDOUZKKFHVEKRI-UHFFFAOYSA-N 0.000 description 1
- 229940046305 5-bromo-5-nitro-1,3-dioxane Drugs 0.000 description 1
- PZEYMDWINYOKTP-UHFFFAOYSA-N CP(=O)(O)[Y] Chemical compound CP(=O)(O)[Y] PZEYMDWINYOKTP-UHFFFAOYSA-N 0.000 description 1
- RYGMFSIKBFXOCR-UHFFFAOYSA-N Copper Chemical compound [Cu] RYGMFSIKBFXOCR-UHFFFAOYSA-N 0.000 description 1
- JDRSMPFHFNXQRB-CMTNHCDUSA-N Decyl beta-D-threo-hexopyranoside Chemical compound CCCCCCCCCCO[C@@H]1O[C@H](CO)C(O)[C@H](O)C1O JDRSMPFHFNXQRB-CMTNHCDUSA-N 0.000 description 1
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 1
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 1
- 239000002202 Polyethylene glycol Substances 0.000 description 1
- ZLMJMSJWJFRBEC-UHFFFAOYSA-N Potassium Chemical compound [K] ZLMJMSJWJFRBEC-UHFFFAOYSA-N 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 1
- 239000004809 Teflon Substances 0.000 description 1
- 229920006362 Teflon® Polymers 0.000 description 1
- 239000013504 Triton X-100 Substances 0.000 description 1
- 229920004890 Triton X-100 Polymers 0.000 description 1
- 238000005411 Van der Waals force Methods 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 150000001298 alcohols Chemical class 0.000 description 1
- 125000003342 alkenyl group Chemical group 0.000 description 1
- 150000004996 alkyl benzenes Chemical class 0.000 description 1
- 125000005599 alkyl carboxylate group Chemical group 0.000 description 1
- 150000005215 alkyl ethers Chemical class 0.000 description 1
- 150000008051 alkyl sulfates Chemical class 0.000 description 1
- 125000005211 alkyl trimethyl ammonium group Chemical group 0.000 description 1
- 125000000304 alkynyl group Chemical group 0.000 description 1
- 229910000147 aluminium phosphate Inorganic materials 0.000 description 1
- 150000001413 amino acids Chemical class 0.000 description 1
- BTBJBAZGXNKLQC-UHFFFAOYSA-N ammonium lauryl sulfate Chemical compound [NH4+].CCCCCCCCCCCCOS([O-])(=O)=O BTBJBAZGXNKLQC-UHFFFAOYSA-N 0.000 description 1
- 229940063953 ammonium lauryl sulfate Drugs 0.000 description 1
- 229910052925 anhydrite Inorganic materials 0.000 description 1
- 125000003118 aryl group Chemical group 0.000 description 1
- 125000004429 atom Chemical group 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 229920001400 block copolymer Polymers 0.000 description 1
- XVBRCOKDZVQYAY-UHFFFAOYSA-N bronidox Chemical compound [O-][N+](=O)C1(Br)COCOC1 XVBRCOKDZVQYAY-UHFFFAOYSA-N 0.000 description 1
- OSGAYBCDTDRGGQ-UHFFFAOYSA-L calcium sulfate Chemical compound [Ca+2].[O-]S([O-])(=O)=O OSGAYBCDTDRGGQ-UHFFFAOYSA-L 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 125000002091 cationic group Chemical group 0.000 description 1
- 229940082500 cetostearyl alcohol Drugs 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- MRUAUOIMASANKQ-UHFFFAOYSA-N cocamidopropyl betaine Chemical compound CCCCCCCCCCCC(=O)NCCC[N+](C)(C)CC([O-])=O MRUAUOIMASANKQ-UHFFFAOYSA-N 0.000 description 1
- 229940073507 cocamidopropyl betaine Drugs 0.000 description 1
- 229910052802 copper Inorganic materials 0.000 description 1
- 239000010949 copper Substances 0.000 description 1
- 229940073499 decyl glucoside Drugs 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- BUACSMWVFUNQET-UHFFFAOYSA-H dialuminum;trisulfate;hydrate Chemical compound O.[Al+3].[Al+3].[O-]S([O-])(=O)=O.[O-]S([O-])(=O)=O.[O-]S([O-])(=O)=O BUACSMWVFUNQET-UHFFFAOYSA-H 0.000 description 1
- 235000014113 dietary fatty acids Nutrition 0.000 description 1
- REZZEXDLIUJMMS-UHFFFAOYSA-M dimethyldioctadecylammonium chloride Chemical compound [Cl-].CCCCCCCCCCCCCCCCCC[N+](C)(C)CCCCCCCCCCCCCCCCCC REZZEXDLIUJMMS-UHFFFAOYSA-M 0.000 description 1
- 235000019329 dioctyl sodium sulphosuccinate Nutrition 0.000 description 1
- SMVRDGHCVNAOIN-UHFFFAOYSA-L disodium;1-dodecoxydodecane;sulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=O.CCCCCCCCCCCCOCCCCCCCCCCCC SMVRDGHCVNAOIN-UHFFFAOYSA-L 0.000 description 1
- SYELZBGXAIXKHU-UHFFFAOYSA-N dodecyldimethylamine N-oxide Chemical compound CCCCCCCCCCCC[N+](C)(C)[O-] SYELZBGXAIXKHU-UHFFFAOYSA-N 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 150000002148 esters Chemical class 0.000 description 1
- 125000001033 ether group Chemical group 0.000 description 1
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- 239000010408 film Substances 0.000 description 1
- 238000009501 film coating Methods 0.000 description 1
- 229930182478 glucoside Natural products 0.000 description 1
- 229940074046 glyceryl laurate Drugs 0.000 description 1
- XLYOFNOQVPJJNP-ZSJDYOACSA-N heavy water Substances [2H]O[2H] XLYOFNOQVPJJNP-ZSJDYOACSA-N 0.000 description 1
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- 125000001841 imino group Chemical group [H]N=* 0.000 description 1
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- QWTDNUCVQCZILF-UHFFFAOYSA-N iso-pentane Natural products CCC(C)C QWTDNUCVQCZILF-UHFFFAOYSA-N 0.000 description 1
- LAPRIVJANDLWOK-UHFFFAOYSA-N laureth-5 Chemical compound CCCCCCCCCCCCOCCOCCOCCOCCOCCO LAPRIVJANDLWOK-UHFFFAOYSA-N 0.000 description 1
- PYIDGJJWBIBVIA-UYTYNIKBSA-N lauryl glucoside Chemical compound CCCCCCCCCCCCO[C@@H]1O[C@H](CO)[C@@H](O)[C@H](O)[C@H]1O PYIDGJJWBIBVIA-UYTYNIKBSA-N 0.000 description 1
- 229940048848 lauryl glucoside Drugs 0.000 description 1
- 229940067606 lecithin Drugs 0.000 description 1
- 235000010445 lecithin Nutrition 0.000 description 1
- 239000000787 lecithin Substances 0.000 description 1
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- 238000002156 mixing Methods 0.000 description 1
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- GOQYKNQRPGWPLP-UHFFFAOYSA-N n-heptadecyl alcohol Natural products CCCCCCCCCCCCCCCCCO GOQYKNQRPGWPLP-UHFFFAOYSA-N 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 229940087419 nonoxynol-9 Drugs 0.000 description 1
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- YYELLDKEOUKVIQ-UHFFFAOYSA-N octaethyleneglycol monododecyl ether Chemical compound CCCCCCCCCCCCOCCOCCOCCOCCOCCOCCOCCOCCO YYELLDKEOUKVIQ-UHFFFAOYSA-N 0.000 description 1
- SMGTYJPMKXNQFY-UHFFFAOYSA-N octenidine dihydrochloride Chemical group Cl.Cl.C1=CC(=NCCCCCCCC)C=CN1CCCCCCCCCCN1C=CC(=NCCCCCCCC)C=C1 SMGTYJPMKXNQFY-UHFFFAOYSA-N 0.000 description 1
- HEGSGKPQLMEBJL-RKQHYHRCSA-N octyl beta-D-glucopyranoside Chemical compound CCCCCCCCO[C@@H]1O[C@H](CO)[C@@H](O)[C@H](O)[C@H]1O HEGSGKPQLMEBJL-RKQHYHRCSA-N 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 229940055577 oleyl alcohol Drugs 0.000 description 1
- XMLQWXUVTXCDDL-UHFFFAOYSA-N oleyl alcohol Natural products CCCCCCC=CCCCCCCCCCCO XMLQWXUVTXCDDL-UHFFFAOYSA-N 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 125000000913 palmityl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])[H] 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- SNGREZUHAYWORS-UHFFFAOYSA-N perfluorooctanoic acid Chemical compound OC(=O)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)C(F)(F)F SNGREZUHAYWORS-UHFFFAOYSA-N 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 125000001997 phenyl group Chemical group [H]C1=C([H])C([H])=C(*)C([H])=C1[H] 0.000 description 1
- 229920001983 poloxamer Polymers 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 229920001223 polyethylene glycol Polymers 0.000 description 1
- 229920000136 polysorbate Polymers 0.000 description 1
- 229940068965 polysorbates Drugs 0.000 description 1
- 229910052700 potassium Inorganic materials 0.000 description 1
- 239000011591 potassium Substances 0.000 description 1
- ARIWANIATODDMH-UHFFFAOYSA-N rac-1-monolauroylglycerol Chemical compound CCCCCCCCCCCC(=O)OCC(O)CO ARIWANIATODDMH-UHFFFAOYSA-N 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 108700004121 sarkosyl Proteins 0.000 description 1
- 239000000344 soap Substances 0.000 description 1
- 229910052708 sodium Inorganic materials 0.000 description 1
- 239000011734 sodium Substances 0.000 description 1
- 229940057950 sodium laureth sulfate Drugs 0.000 description 1
- KSAVQLQVUXSOCR-UHFFFAOYSA-M sodium lauroyl sarcosinate Chemical compound [Na+].CCCCCCCCCCCC(=O)N(C)CC([O-])=O KSAVQLQVUXSOCR-UHFFFAOYSA-M 0.000 description 1
- 229940045885 sodium lauroyl sarcosinate Drugs 0.000 description 1
- MDSQKJDNWUMBQQ-UHFFFAOYSA-M sodium myreth sulfate Chemical compound [Na+].CCCCCCCCCCCCCCOCCOCCOCCOS([O-])(=O)=O MDSQKJDNWUMBQQ-UHFFFAOYSA-M 0.000 description 1
- RYYKJJJTJZKILX-UHFFFAOYSA-M sodium octadecanoate Chemical compound [Na+].CCCCCCCCCCCCCCCCCC([O-])=O RYYKJJJTJZKILX-UHFFFAOYSA-M 0.000 description 1
- SXHLENDCVBIJFO-UHFFFAOYSA-M sodium;2-[2-(2-dodecoxyethoxy)ethoxy]ethyl sulfate Chemical compound [Na+].CCCCCCCCCCCCOCCOCCOCCOS([O-])(=O)=O SXHLENDCVBIJFO-UHFFFAOYSA-M 0.000 description 1
- 229940012831 stearyl alcohol Drugs 0.000 description 1
- 238000003756 stirring Methods 0.000 description 1
- 150000003467 sulfuric acid derivatives Chemical class 0.000 description 1
- 239000003760 tallow Substances 0.000 description 1
- FBWNMEQMRUMQSO-UHFFFAOYSA-N tergitol NP-9 Chemical compound CCCCCCCCCC1=CC=C(OCCOCCOCCOCCOCCOCCOCCOCCOCCO)C=C1 FBWNMEQMRUMQSO-UHFFFAOYSA-N 0.000 description 1
- DLYUQMMRRRQYAE-UHFFFAOYSA-N tetraphosphorus decaoxide Chemical compound O1P(O2)(=O)OP3(=O)OP1(=O)OP2(=O)O3 DLYUQMMRRRQYAE-UHFFFAOYSA-N 0.000 description 1
- OULAJFUGPPVRBK-UHFFFAOYSA-N tetratriacontyl alcohol Natural products CCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCCO OULAJFUGPPVRBK-UHFFFAOYSA-N 0.000 description 1
- 239000010409 thin film Substances 0.000 description 1
- 230000001052 transient effect Effects 0.000 description 1
- LGQXXHMEBUOXRP-UHFFFAOYSA-N tributyl borate Chemical compound CCCCOB(OCCCC)OCCCC LGQXXHMEBUOXRP-UHFFFAOYSA-N 0.000 description 1
- DQWPFSLDHJDLRL-UHFFFAOYSA-N triethyl phosphate Chemical compound CCOP(=O)(OCC)OCC DQWPFSLDHJDLRL-UHFFFAOYSA-N 0.000 description 1
Images
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
- C09K8/64—Oil-based compositions
-
- 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
-
- 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
- C09K2208/26—Gel breakers other than bacteria or enzymes
Definitions
- This document relates to methods of treating a subterranean formation containing hydrocarbons.
- a formation can be fractured to attempt to achieve higher production rates.
- Proppant and fracturing fluid are pumped into a well that penetrates an oil or gas bearing formation. High pressure is applied to the well, the formation fractures and proppant carried by the fracturing fluid flows into the fractures. The proppant in the fractures holds the fractures open after the pressure is relaxed and production is resumed.
- fracturing fluid including liquefied petroleum gas (LPG).
- LPG liquefied petroleum gas
- Various chemicals may be added to the fracturing fluid, such as gelling agents, breakers, activators, and surfactants.
- a method of treating a subterranean formation containing hydrocarbons comprising: modifying the subterranean formation with a surface energy reducing agent; and injecting into the subterranean formation a fracturing fluid containing a base fluid and a gelling agent; in which the surface energy reducing agent is selected to effectively reduce the surface energy of the subterranean formation to at or below the surface tension of the gelling agent.
- the surface energy reducing agent is selected such that the modified subterranean formation does not bond with the gelling agent.
- the surface energy reducing agent adheres to the subterranean formation more strongly than the gelling agent adheres to the subterranean formation.
- the surface energy reducing agent is selected to effectively reduce the net force of adhesion between the subterranean formation and the gelling agent (F FG ) from above to below the net force of cohesion of the gelling agent (F GG ).
- the method comprises breaking a gel, formed of the gelling agent, in the subterranean formation, in which the surface energy reducing agent is selected to effectively reduce the surface energy of the subterranean formation to at or below the surface tension of the gelling agent when broken.
- Modifying is carried out by injecting fracturing fluid comprising the surface energy reducing agent. Modifying comprises coating.
- the surface energy reducing agent comprises a surfactant.
- the surfactant comprises one or more of an ionic surfactant and a non-ionic surfactant.
- the ionic surfactant comprises one or more of an anionic surfactant, a cationic surfactant, and a zwitterionic surfactant.
- the surface energy reducing agent comprises an alkyne-diol.
- the surface energy reducing agent comprises one or more of Surfanol MB, Surfanol 104-PG50, Surfanol 2502, Dynol 604, and Dynol 607.
- the base fluid comprises hydrocarbons and the gelling agent comprises a gelling agent for hydrocarbons.
- the gelling agent comprises a polyacrylimide.
- the gelling agent comprises a phosphate.
- the base fluid comprises liquefied petroleum gas.
- the gelling agent comprises a gelling agent for liquefied petroleum gas.
- the gelling agent is selected to have a surface tension of between twenty and forty-six dynes/cm when in the subterranean formation after breaking.
- FIG. 1A is side elevation view of an apparatus for treating a subterranean formation.
- FIG. 1B is a flow diagram of a method of treating a subterranean formation containing hydrocarbons.
- FIG. 2A is an exploded view that illustrates a gelling agent adhering to an untreated formation.
- FIG. 2B is an exploded view that illustrates the reduced adherence of gelling agent to the formation of FIG. 2A after coating, for example adsorbing, the formation with surface energy reducing agent.
- FIGS. 3A-F are photographs of a formation test surface coated with no surfactant, Surfanol MB, Surfanol 104-PG50, Surfanol 2502, Dynol 604, and Dynol 607, respectively, immersed in gelled pentane, and spotted with accudyne pens of varying surface tensions.
- Dispersive adhesion similar to chemical adhesion, occurs when two materials are held together by van der Waals forces, which involve the attraction between slightly charged molecules, such as polar compounds.
- Positive and negative poles may be a permanent property of a molecule (Keesom forces) or a transient effect which can occur in any molecule (London forces).
- adhesion usually refers to dispersive adhesion.
- contact angle may quantify adhesiveness.
- the amount of adhesion is related to the difference between the surface energy of the surface and the surface tension of the liquid.
- Surface energy is the excess energy at the surface of a material compared with the material as a whole.
- Surface tension refers to the surface energy of a liquid.
- the contact angle of a three-phase system is a function not only of dispersive adhesion between the molecules in the liquid and the molecules in the solid, but also cohesion, which is dispersive interaction between like liquid molecules. Strong adhesion and weak cohesion may result in a high degree of wetting (ex. FIG. 2A ), which may be a lyophilic condition with low measured contact angles. Conversely, weak adhesion and strong cohesion may result in lyophobic conditions with high measured contact angles and poor wetting ( FIG. 2B ). Table 1 below illustrates surface energies from some example materials.
- Subterranean formation 24 is a hydrocarbon reservoir, which may be treated for example by injection through a well 22 penetrating the hydrocarbon reservoir 24 .
- Fracturing fluid base fluid may be initially contained within a storage tank 10 .
- Tank 10 may comprise a tanker truck or a large vessel.
- a generic example treatment of subterranean formation 24 goes as follows.
- the fracturing fluid may be pumped from reservoir 10 down line 12 , where various components may be added to the fluid, for example via one or more component addition systems 14 , 16 , 18 .
- components such as gelling agent and proppant may be added from addition systems 16 and 18 , respectively.
- the addition systems may be, for example, hoppers.
- a frac pressure pump 20 injects the frac fluid down a well 22 and into subterranean formation 24 .
- one or more component or fluid may be added to the frac fluid after the pump 20 .
- the concept of reservoir treatment is well known, and the details need not be described here.
- pressure may be applied to the frac fluid injected into the subterranean formation 24 .
- the pressure may be sufficient to cause fracturing of the subterranean formation.
- the subterranean formation 24 is modified with a surface energy reducing agent, for example from addition system 18 .
- Modifying may be carried out by injecting fracturing fluid comprising the surface energy reducing agent.
- fracturing fluid comprising the surface energy reducing agent.
- a pad of base fluid from tank 10 may be combined with surface energy reducing agent from addition unit 18 , and pumped via frac pressure pump 20 down well 22 .
- the surface energy reducing agent may also be injected neat or with another suitable fluid.
- the surface energy reducing agent may coat the formation ( FIG. 2B ) and effectively reducing the surface energy of the formation.
- substantially the entire surface area of the subterranean formation that will come into contact with the fracturing fluid is coated.
- the surface energy reducing agent is supplied throughout the entire injection of frac fluid.
- the proppant used such as sand, may be pre-coated or co-injected with surface energy reducing agent. Coating a surface reduces roughness of the coated surface and thus is beneficial as adherence may increase with greater degrees of roughness.
- a fracturing fluid containing a base fluid, for example from tank 10 , and a gelling agent, for example from addition unit 16 is injected into the subterranean formation 24 .
- the treatment which may be a fracturing treatment, may then be completed, for example by pressuring up the fluid in well 22 to frac, and delivering proppant from addition unit 16 into the fractures formed in the subterranean formation.
- FIG. 2A illustrates a situation where the injected gelling agent 46 has a surface tension that is lower than the surface energy of the formation 24 .
- a contact angle 45 less than 90 degrees indicates high adherence.
- the surface energy of the formation 24 will be larger than the surface tension of the gelling agent 46 , effectively causing gelling agent 46 to wet and adhere to the formation 24 .
- FIG. 2B illustrates the beneficial effect of the surface energy reducing agent 44 , which has been selected to effectively reduce the surface energy of the formation 24 to at or below the surface tension of the gelling agent 46 .
- the contact angle 45 is greater than 90 degrees, indicating a low degree of wetting, and likely a low degree of adherence.
- the surface energy reducing agent 44 must reduce the surface energy to thirty-five dynes/cm or lower, for example down to twenty dynes/cm. In most cases, the desired result will be achieved if the surface energy reducing agent 44 is selected to reduce the net force of adhesion between the subterranean formation 24 and the gelling agent (F FG ) from above to below the net force of cohesion of the gelling agent (F GG ).
- the surface energy reducing agent 44 may be selected such that the modified subterranean formation shown in FIG. 2B does not bond, for example chemically, with the gelling agent 46 .
- the surface energy reducing agent 44 may be selected to form a hydrophobic coating if the gelling agent 46 is known to be hydrophilic. Thus, when the frac pressure is reduced and flowback induced, gelling agent 46 is able to slide off of formation 24 and be removed from the well 22 .
- the surface energy reducing agent 44 may also be selected to adhere to the subterranean formation 24 more strongly than the gelling agent 46 adheres to the subterranean formation 24 .
- the gelling agent 46 selected may have a surface tension of between twenty and forty-six dynes/cm when in the subterranean formation after breaking.
- the method includes the stage of breaking a gel, formed of the gelling agent 46 , in the subterranean formation 24 , in which the surface energy reducing agent 44 is selected to effectively reduce the surface energy of the subterranean formation 24 to at or below the surface tension of the gelling agent 46 when broken.
- the broken gelling agent is targeted by the surface energy reducing agent 44 , as it is broken gel that may be left in formation 24 . This may be a consideration if the gelling agent changes surface tension upon breaking due to a chemical change in the gelling agent.
- the surface energy reducing agent may make the formation 24 omniphobic, in order to allow easy removal of the base fluid as well as the fracturing chemicals.
- the surface energy reducing agent may comprise a surfactant, such as an alkyne-diol.
- a surfactant such as an alkyne-diol.
- a solid spot produced by a pen with a surface tension X indicates that the formation has a surface energy above X, while a splotchy or beaded spot produced by the same pen indicates low adherence due to the fact that the formation has a surface energy at or below X.
- reference numerals 54 , 56 , 58 , 60 , 62 , and 64 identify spots made by accudyne pens of surface tensions 30 , 32 , 34 , 36 , 38 , and 40 dynes/cm, respectively.
- FIG. 3A was used as a blank formation sample 24 , with no surface energy reducing agent added to the gelled pentane.
- the surface energy reducing agent comprises Surfanol MB ( FIG. 3B ), Surfanol 104-PG50 ( FIG. 3C ), Surfanol 2502 ( FIG. 3D ), Dynol 604 ( FIG. 3E ), and Dynol 607 ( FIG. 3F ).
- FIG. 3A where no surface energy reducing agent was used, accudyne pens having surface tensions 34 dynes/cm and 36 dynes/cm were able to clearly form solid spots 58 and 60 , respectively, indicating that the surface energy of formation sample 24 was at least greater than 36 dynes/cm and likely much higher.
- the surfactants used in FIGS. 3B-F all effectively reduced the surface energy of formation 24 sample, as evidenced by the beaded spots left by most of the pens.
- Table 2 indicates the estimated effective surface energy of the modified formation 24 samples based on the tesing.
- the base fluid may comprise hydrocarbons, such as C 6 -C 20 hydrocarbons, and the gelling agent may comprise a gelling agent for hydrocarbons.
- the gelling agent may comprise a phosphate based chemical.
- the base fluid may be water, and the gelling agent may be a gelling agent for water.
- the base fluid may comprise liquefied petroleum gas, and the gelling agent may comprise a gelling agent for liquefied petroleum gas.
- LPG has been advantageously used as a fracturing fluid to simplify the recovery and clean-up of frac fluids after a frac. Exemplary LPG frac systems are disclosed in WO2007098606, incorporated herein by reference.
- a suitable gelling agent for LPG is created by first reacting diphosphorous pentoxide with triethyl phosphate and an alcohol having hydrocarbon chains of 3-7 carbons long, or in a further for example alcohols having hydrocarbon chains 4-6 carbons long. The orthophosphate acid ester formed is then reacted with aluminum sulphate to create the desired gelling agent.
- the gelling agent created will have hydrocarbon chains from 3-7 carbons long or, as in the further example, 4-6 carbons long.
- the hydrocarbon chains of the gelling agent are thus commensurate in length with the hydrocarbon chains of liquid petroleum gas used for the frac fluid.
- This gelling agent is more effective at gelling a propane or butane fluid than a gelling agent with longer hydrocarbon chains.
- the proportion of gelling agent in the frac fluid is adjusted to obtain a suitable viscosity in the gelled frac fluid.
- a volatile-phosphorus free gelling agent may be used, for example for gelling hydrocarbons.
- a gelling agent may have the general formula of:
- Such gelling agent may be made as follows. Phosphorus oxyhalide is reacted with a chemical reagent to produce substantially only diester phosphorus oxyhalide, the chemical reagent comprising at least one of an organic alcohol having 2-24 carbon atoms, an organic amine with an organic group having 2-24 carbon atoms, and an organic sulfide having 2-24 carbon atoms. The diester phosphorus oxyhalide is then hydrolyzed to produce diester phosphoric acid. Further examples are given in WO/2010/022496, incorporated herein by reference.
- LPG may include a variety of petroleum and natural gases existing in a liquid state at ambient temperatures and moderate pressures. In some cases, LPG refers to a mixture of such fluids. These mixes are generally more affordable and easier to obtain than any one individual LPG, since they are hard to separate and purify individually. Unlike conventional hydrocarbon based fracturing fluids, common LPGs are tightly fractionated products resulting in a high degree of purity and very predictable performance. Exemplary LPGs include ethane, propane, butane, or various mixtures thereof. As well, exemplary LPGs also include isomers of propane and butane, such as iso-butane. Further LPG examples include HD-5 propane, commercial butane, and n-butane. The LPG mixture may be controlled to gain the desired hydraulic fracturing and clean-up performance. LPG fluids used may also include minor amounts of pentane (such as i-pentane or n-pentane), and higher weight hydrocarbons.
- pentane such as
- LPGs tend to produce excellent fracturing fluids.
- LPG is readily available, cost effective and is easily and safely handled on surface as a liquid under moderate pressure.
- LPG is completely compatible with formations and formation fluids, is highly soluble in formation hydrocarbons and eliminates phase trapping—resulting in increased well production.
- LPG may be readily and predictably viscosified to generate a fluid capable of efficient fracture creation and excellent proppant transport. After fracturing, LPG may be recovered very rapidly, allowing savings on clean up costs.
- LPG may be predominantly propane, butane, or a mixture of propane and butane.
- LPG may comprise more than 80%, 90%, or 95% propane, butane, or a mixture of propane and butane.
- Exemplary gelling agents that may be used are disclosed by Whitney in U.S. Pat. Nos. 3,775,069 and 3,846,310, the specifications of which are incorporated by reference. Such gelling agents may create water-sensitive gels.
- An example of a suitable gelling agent comprises a combination of an alkoxide of a group IIIA element and an alkoxide of an alkali metal. When combined, the alkoxide of the group IIIA element and the alkoxide of the alkali metal react to form a polymer gel.
- the group IIIA element may comprise one or more of boron and aluminum for example.
- Each of the organic groups of R 1 , R 2 , and R 3 may have 2-10 carbon atoms, and may comprise an alkyl group.
- M 1 boron
- R 1 , R 2 , and R 3 comprise 2-10 carbon atoms.
- the alkali metal may comprise one or more of lithium, sodium, and potassium for example.
- the organic group of R 4 may comprise 2-24 carbon atoms, for further example 12 carbon atoms, and may comprise an alkyl group.
- M 2 lithium and the organic group of R 4 comprises 2-24 carbon atoms.
- R 4 may further comprise: (AQ) n (R 5 ) x (R 6 ) y .
- A is an organic group
- Q is O or N
- n is 1-10
- R 5 and R 6 are organic groups
- x is either 1 or 2 depending on the valence of Q
- y is 0 or 1 depending on the valence of Q.
- the alkoxide of an alkali metal formed would have the formula of M 2 O(AQ) n (R 5 ) x (R) y .
- A may have 2-4 carbon atoms.
- Organic groups as disclosed herein may refer to groups with at least one carbon atom, as long the resulting gelling agent is suitable for its purpose. Examples of organic groups include phenyl, aryl, alkenyl, alkynyl, cyclo, and ether groups.
- a suitable amount of gelling agent may be used, for example 0.25-5% by weight of the fracturing fluid.
- the a suitable ration of the alkoxide of a group IIIA element and the alkoxide of an alkali metal may be used, for example 3:1 to 1:3, with 1:1 being a preferable ratio.
- Exemplary breakers for use with water-sensitive gels include hydrated breakers.
- the hydrated breaker may comprise one or more hydrates, wherein water of the one or more hydrates is releasable so as to act with the water-sensitive carrier to reduce the viscosity of the fracturing fluid.
- a hydrated breaker may have a crystalline framework containing water that is bound within the crystalline framework and releasable into the fracturing fluid to act on the water-sensitive gel to reduce the viscosity of the fracturing fluid. Hydrated breakers are disclosed for example in U.S. application Ser. No. 12/609,893 and CA Application No. 2685298 the content of which is incorporated here by reference where permitted by law.
- a gelling agent need not be specifically targeted by the surface energy reducing agent.
- the surface energy reducing agent may be selected to effectively reduce the surface energy of the subterranean formation to at or below the surface tension of one or more of the base fluid, breaker, activator, gelling agent, or other treating chemical.
- the targeted injected chemicals may be easily removed after treatment is complete, and potential for well damage by tacky chemicals is reduced or eliminated.
- the surfactant may comprise one or more of an ionic surfactant and a non-ionic surfactant.
- the ionic surfactant may comprise one or more of an anionic surfactant, a cationic surfactant, and a zwitterionic surfactant.
- Anionic surfactants may be based on permanent anions such as sulfate, sulfonate, and phosphate, or pH-dependent anions such as carboxylate.
- Example anionic surfactants based on sulfates include alkyl sulfates such as ammonium lauryl sulfate and sodium lauryl sulfate (SDS), alkyl ether sulfates such as sodium laureth sulfate (also known as sodium lauryl ether sulfate or SLES), and sodium myreth sulfate.
- Example anionic surfactants based on sulfonates include docusates such as dioctyl sodium sulfosuccinate.
- Example anionic surfactants based on sulfonates also include sulfonate fluorosurfactants such as perfluorooctanesulfonate (PFOS), and perfluorobutanesulfonate.
- Example anionic surfactants based on sulfonates also include alkyl benzene sulfonates.
- Example anionic surfactants based on phosphates include alkyl aryl ether phosphate and alkyl ether phosphate.
- Example anionic surfactants based on carboxylates include alkyl carboxylates such as fatty acid salts (soaps) and sodium stearate.
- Example anionic surfactants based on carboxylates also include sodium lauroyl sarcosinate.
- Example anionic surfactants based on carboxylates also include carboxylate fluorosurfactants such as perfluorononanoate, and perfluorooctanoate (PFOA or PFO).
- Cationic surfactants may be based on pH-dependent amines or permanently charged quaternary ammonium cations.
- Example cationic surfactants based on pH-dependent amines include primary, secondary or tertiary amines. For example, primary amines may be used that become positively charged at pH ⁇ 10, and secondary amines may be used that become charged at pH ⁇ 4.
- One example of a pH-dependent amine is octenidine dihydrochloride.
- Example cationic surfactants based on permanently charged quaternary ammonium cations include alkyltrimethylammonium salts such as cetyl trimethylammonium bromide (CTAB a.k.a.
- Example cationic surfactants based on permanently charged quaternary ammonium cations also include cetylpyridinium chloride (CPC), polyethoxylated tallow amine (POEA), benzalkonium chloride (BAC), benzethonium chloride (BZT), 5-bromo-5-nitro-1,3-dioxane, dimethyldioctadecylammonium chloride, and dioctadecyldimethylammonium bromide (DODAB).
- CPC cetylpyridinium chloride
- POEA polyethoxylated tallow amine
- BAC benzalkonium chloride
- BZT benzethonium chloride
- DODAB dioctadecyldimethylammonium bromide
- Zwitterionic surfactants which may be amphoteric, may be based on primary, secondary or tertiary amines or quaternary ammonium cations with sulfonate, carboxylate, or phosphate anions.
- Example zwitterionic surfactants with sulfonates include CHAPS ( 3 -[(3-Cholamidopropyl)dimethylammonio]-1-propanesulfonate), and sultaines such as cocamidopropyl hydroxysultaine.
- Example zwitterionic surfactants with carboxylates include amino acids, imino acids, and betaines such as cocamidopropyl betaine.
- Example zwitterionic surfactants with phosphates include lecithin.
- Nonionic surfactants may include fatty alcohols such as cetyl alcohol, stearyl alcohol, cetostearyl alcohol (for example comprising predominantly of cetyl and stearyl alcohols), and oleyl alcohol.
- Nonionic surfactants may also include polyoxyethylene glycol alkyl ethers (Brij or CH 3 —(CH 2 ) 10-16 —(O—C 2 H 4 ) 1-25 —OH) such as octaethylene glycol monododecyl ether, and pentaethylene glycol monododecyl ether.
- Nonionic surfactants may also include polyoxypropylene glycol alkyl ethers (CH 3 —(CH 2 ) 10-16 —(O—C 3 H 6 ) 1-25 —OH).
- Nonionic surfactants may also include glucoside alkyl ethers (CH 3 —(CH 2 ) 10-16 —(O-Glucoside) 1-3 -OH) such as decyl glucoside, lauryl glucoside, and octyl glucoside.
- Nonionic surfactants may also include polyoxyethylene glycol octylphenol ethers (C 8 H 17 —(C 6 H 4 )—(O—C 2 H 4 ) 1-25 —OH) such as Triton X-100.
- Nonionic surfactants may also include polyoxyethylene glycol alkylphenol ethers (C 9 H 19 —(C 6 H 4 )—(O—C 2 H 4 ) 1-25 —OH) such as nonoxynol-9.
- Nonionic surfactants may also include glycerol alkyl esters such as glyceryl laurate.
- Nonionic surfactants may also include polyoxyethylene glycol sorbitan alkyl esters such as polysorbates.
- Nonionic surfactants may also include sorbitan alkyl esters such as spans.
- Nonionic surfactants may also include cocamide MEA, and cocamide DEA.
- Nonionic surfactants may also include dodecyl dimethylamine oxide, and block copolymers of polyethylene glycol and polypropylene glycol such as poloxamers.
- LP10 is a broken dialkyl phosphate LPG gel.
Abstract
A method of treating a subterranean formation containing hydrocarbons is disclosed, the method comprising: modifying the subterranean formation with a surface energy reducing agent; and injecting into the subterranean formation a fracturing fluid containing a base fluid and a gelling agent; in which the surface energy reducing agent is selected to effectively reduce the surface energy of the subterranean formation to at or below the surface tension of the gelling agent.
Description
- This application claims the benefit under 35 U.S.C. §119(e) of Provisional Application No. 61/433,076, filed Jan. 14, 2012.
- This document relates to methods of treating a subterranean formation containing hydrocarbons.
- In the conventional fracturing of wells, producing formations, new wells or low producing wells that have been taken out of production, a formation can be fractured to attempt to achieve higher production rates. Proppant and fracturing fluid are pumped into a well that penetrates an oil or gas bearing formation. High pressure is applied to the well, the formation fractures and proppant carried by the fracturing fluid flows into the fractures. The proppant in the fractures holds the fractures open after the pressure is relaxed and production is resumed. Various fluids have been disclosed for use as the fracturing fluid, including liquefied petroleum gas (LPG). Various chemicals may be added to the fracturing fluid, such as gelling agents, breakers, activators, and surfactants.
- A method of treating a subterranean formation containing hydrocarbons is disclosed, the method comprising: modifying the subterranean formation with a surface energy reducing agent; and injecting into the subterranean formation a fracturing fluid containing a base fluid and a gelling agent; in which the surface energy reducing agent is selected to effectively reduce the surface energy of the subterranean formation to at or below the surface tension of the gelling agent.
- In various embodiments, there may be included any one or more of the following features: The surface energy reducing agent is selected such that the modified subterranean formation does not bond with the gelling agent. The surface energy reducing agent adheres to the subterranean formation more strongly than the gelling agent adheres to the subterranean formation. The surface energy reducing agent is selected to effectively reduce the net force of adhesion between the subterranean formation and the gelling agent (FFG) from above to below the net force of cohesion of the gelling agent (FGG). The method comprises breaking a gel, formed of the gelling agent, in the subterranean formation, in which the surface energy reducing agent is selected to effectively reduce the surface energy of the subterranean formation to at or below the surface tension of the gelling agent when broken. Modifying is carried out by injecting fracturing fluid comprising the surface energy reducing agent. Modifying comprises coating. The surface energy reducing agent comprises a surfactant. The surfactant comprises one or more of an ionic surfactant and a non-ionic surfactant. The ionic surfactant comprises one or more of an anionic surfactant, a cationic surfactant, and a zwitterionic surfactant. The surface energy reducing agent comprises an alkyne-diol. The surface energy reducing agent comprises one or more of Surfanol MB, Surfanol 104-PG50, Surfanol 2502, Dynol 604, and Dynol 607. The base fluid comprises hydrocarbons and the gelling agent comprises a gelling agent for hydrocarbons. The gelling agent comprises a polyacrylimide. The gelling agent comprises a phosphate. The base fluid comprises liquefied petroleum gas. The gelling agent comprises a gelling agent for liquefied petroleum gas. The gelling agent is selected to have a surface tension of between twenty and forty-six dynes/cm when in the subterranean formation after breaking.
- These and other aspects of the device and method are set out in the claims, which are incorporated here by reference.
- Embodiments will now be described with reference to the figures, in which like reference characters denote like elements, by way of example, and in which:
-
FIG. 1A is side elevation view of an apparatus for treating a subterranean formation. -
FIG. 1B is a flow diagram of a method of treating a subterranean formation containing hydrocarbons. -
FIG. 2A is an exploded view that illustrates a gelling agent adhering to an untreated formation. -
FIG. 2B is an exploded view that illustrates the reduced adherence of gelling agent to the formation ofFIG. 2A after coating, for example adsorbing, the formation with surface energy reducing agent. -
FIGS. 3A-F are photographs of a formation test surface coated with no surfactant, Surfanol MB, Surfanol 104-PG50, Surfanol 2502, Dynol 604, and Dynol 607, respectively, immersed in gelled pentane, and spotted with accudyne pens of varying surface tensions. - Immaterial modifications may be made to the embodiments described here without departing from what is covered by the claims.
- During well treatment, gelling agents or other injected chemicals may stick to the formation on flowback, reducing permeability and potentially plugging the well. Surface science has identified at least five mechanisms of adhesion to explain why one material sticks to another, namely mechanical adhesion, electrostatic adhesion, chemical adhesion, dispersive adhesion, and diffusive adhesion. Regarding the adherence of a liquid to a solid or coated solid in a downhole environment, the latter three appear most relevant. Chemical adhesion occurs when two materials form a compound at the join. Ionic, covalent, and hydrogen bonding are examples of chemical adhesion. Diffusive adhesion occurs when materials merge at the joint by diffusion, for example if the molecules of the liquid are mobile and soluble in the solid or liquid coating the solid. Dispersive adhesion, similar to chemical adhesion, occurs when two materials are held together by van der Waals forces, which involve the attraction between slightly charged molecules, such as polar compounds. Positive and negative poles may be a permanent property of a molecule (Keesom forces) or a transient effect which can occur in any molecule (London forces).
- In surface science, adhesion usually refers to dispersive adhesion. In a solid-liquid-gas system (such as a drop of liquid on a solid surrounded by air) contact angle may quantify adhesiveness. In general, where the
contact angle 45 is low (ex.FIG. 2A ) more adhesion is present than when thecontact angle 45 is large (ex.FIG. 2B ). The amount of adhesion is related to the difference between the surface energy of the surface and the surface tension of the liquid. Surface energy is the excess energy at the surface of a material compared with the material as a whole. Surface tension refers to the surface energy of a liquid. Regardless, the contact angle of a three-phase system is a function not only of dispersive adhesion between the molecules in the liquid and the molecules in the solid, but also cohesion, which is dispersive interaction between like liquid molecules. Strong adhesion and weak cohesion may result in a high degree of wetting (ex.FIG. 2A ), which may be a lyophilic condition with low measured contact angles. Conversely, weak adhesion and strong cohesion may result in lyophobic conditions with high measured contact angles and poor wetting (FIG. 2B ). Table 1 below illustrates surface energies from some example materials. -
TABLE 1 Example Surface Energies SURFACE ENERGY/TENSION SURFACE (Dynes/cm) Copper 1,103 Sand 1000 Aluminum 840 Water 72 Broken Polyacrylimide Gel 35 Hydrocarbons 20-30 Propane <20 Teflon (DuPont) 18 - Referring to
FIG. 1A , asystem 11 for treating asubterranean formation 24 containing hydrocarbons is illustrated.Subterranean formation 24 is a hydrocarbon reservoir, which may be treated for example by injection through a well 22 penetrating thehydrocarbon reservoir 24. Fracturing fluid base fluid may be initially contained within astorage tank 10.Tank 10 may comprise a tanker truck or a large vessel. - A generic example treatment of
subterranean formation 24 goes as follows. The fracturing fluid may be pumped fromreservoir 10 downline 12, where various components may be added to the fluid, for example via one or morecomponent addition systems addition systems frac pressure pump 20 injects the frac fluid down a well 22 and intosubterranean formation 24. In some cases, one or more component or fluid may be added to the frac fluid after thepump 20. The concept of reservoir treatment is well known, and the details need not be described here. In fracturing treatments, pressure may be applied to the frac fluid injected into thesubterranean formation 24. The pressure may be sufficient to cause fracturing of the subterranean formation. - Referring to
FIG. 1B , a method of treatingsubterranean formation 24 is illustrated. The method will now be described with reference to the other Figures. Referring toFIG. 1A , in astage 40, thesubterranean formation 24 is modified with a surface energy reducing agent, for example fromaddition system 18. Modifying may be carried out by injecting fracturing fluid comprising the surface energy reducing agent. For example, a pad of base fluid fromtank 10 may be combined with surface energy reducing agent fromaddition unit 18, and pumped viafrac pressure pump 20 down well 22. However, the surface energy reducing agent may also be injected neat or with another suitable fluid. As the surface energy reducing agent contacts the subterranean formation, the surface energy reducing agent may coat the formation (FIG. 2B ) and effectively reducing the surface energy of the formation. In some embodiments substantially the entire surface area of the subterranean formation that will come into contact with the fracturing fluid is coated. In some cases, the surface energy reducing agent is supplied throughout the entire injection of frac fluid. In some embodiments, the proppant used, such as sand, may be pre-coated or co-injected with surface energy reducing agent. Coating a surface reduces roughness of the coated surface and thus is beneficial as adherence may increase with greater degrees of roughness. - In a
stage 42, a fracturing fluid containing a base fluid, for example fromtank 10, and a gelling agent, for example fromaddition unit 16, is injected into thesubterranean formation 24. The treatment, which may be a fracturing treatment, may then be completed, for example by pressuring up the fluid in well 22 to frac, and delivering proppant fromaddition unit 16 into the fractures formed in the subterranean formation. - Referring to
FIGS. 2A and 2B , the effect of the surfaceenergy reducing agent 44 will now be described.FIG. 2A illustrates a situation where the injected gellingagent 46 has a surface tension that is lower than the surface energy of theformation 24. As is shown, acontact angle 45 less than 90 degrees indicates high adherence. In most formations, for example sandstone formations, the surface energy of theformation 24 will be larger than the surface tension of the gellingagent 46, effectively causing gellingagent 46 to wet and adhere to theformation 24.FIG. 2B illustrates the beneficial effect of the surfaceenergy reducing agent 44, which has been selected to effectively reduce the surface energy of theformation 24 to at or below the surface tension of the gellingagent 46. InFIG. 2B , thecontact angle 45 is greater than 90 degrees, indicating a low degree of wetting, and likely a low degree of adherence. Thus, for a polymer gel such as polyacrylamide gel with a surface tension of 35, the surfaceenergy reducing agent 44 must reduce the surface energy to thirty-five dynes/cm or lower, for example down to twenty dynes/cm. In most cases, the desired result will be achieved if the surfaceenergy reducing agent 44 is selected to reduce the net force of adhesion between thesubterranean formation 24 and the gelling agent (FFG) from above to below the net force of cohesion of the gelling agent (FGG). - The surface
energy reducing agent 44 may be selected such that the modified subterranean formation shown inFIG. 2B does not bond, for example chemically, with the gellingagent 46. For example, the surfaceenergy reducing agent 44 may be selected to form a hydrophobic coating if the gellingagent 46 is known to be hydrophilic. Thus, when the frac pressure is reduced and flowback induced, gellingagent 46 is able to slide off offormation 24 and be removed from thewell 22. The surfaceenergy reducing agent 44 may also be selected to adhere to thesubterranean formation 24 more strongly than the gellingagent 46 adheres to thesubterranean formation 24. Thus, diffusion of the gellingagent 46 into the thin film coating formed by the surfaceenergy reducing agent 46 does not result in gellingagent 46 displacing surfaceenergy reducing agent 44 and adhering to theformation 24. However, in some cases this is not required, and a thin low adherence film of surface energy reducing agent may be sufficient to allow substantial removal of gelling agent and related chemicals from thewell 22. - The gelling
agent 46 selected may have a surface tension of between twenty and forty-six dynes/cm when in the subterranean formation after breaking. In some cases the method includes the stage of breaking a gel, formed of the gellingagent 46, in thesubterranean formation 24, in which the surfaceenergy reducing agent 44 is selected to effectively reduce the surface energy of thesubterranean formation 24 to at or below the surface tension of the gellingagent 46 when broken. Thus, the broken gelling agent is targeted by the surfaceenergy reducing agent 44, as it is broken gel that may be left information 24. This may be a consideration if the gelling agent changes surface tension upon breaking due to a chemical change in the gelling agent. The surface energy reducing agent may make theformation 24 omniphobic, in order to allow easy removal of the base fluid as well as the fracturing chemicals. - Referring to
FIGS. 3A-F , the surface energy reducing agent may comprise a surfactant, such as an alkyne-diol. Accudyne testing was carried out on aformation 24 sample immersed in pentane gelled with 16 L/m3 gel, 16 L/m3 activator, and 8 L/m3 breaker. The formation sample tested was a shale sample from Alberta. In this test, a surface energy reducing agent was introduced and coated onformation 24 sample. Afterwards, accudyne pens of different surface tensions were spotted on theformation 24 sample, in order to determine if surface energy had been reduced. In general, a solid spot produced by a pen with a surface tension X indicates that the formation has a surface energy above X, while a splotchy or beaded spot produced by the same pen indicates low adherence due to the fact that the formation has a surface energy at or below X. For ease of illustration,reference numerals surface tensions FIG. 3A was used as ablank formation sample 24, with no surface energy reducing agent added to the gelled pentane. InFIGS. 3B-F , the surface energy reducing agent comprises Surfanol MB (FIG. 3B ), Surfanol 104-PG50 (FIG. 3C ), Surfanol 2502 (FIG. 3D ), Dynol 604 (FIG. 3E ), and Dynol 607 (FIG. 3F ). InFIG. 3A where no surface energy reducing agent was used, accudyne pens havingsurface tensions 34 dynes/cm and 36 dynes/cm were able to clearly formsolid spots formation sample 24 was at least greater than 36 dynes/cm and likely much higher. By contrast, the surfactants used inFIGS. 3B-F all effectively reduced the surface energy offormation 24 sample, as evidenced by the beaded spots left by most of the pens. The following Table 2 indicates the estimated effective surface energy of the modifiedformation 24 samples based on the tesing. -
TABLE 2 Accudyne Test Results Effective Surface Energy of Fig. Surfactant added Modified Formation 24 Sample3A none >36 (likely much higher) 3B Surfanol MB <30 3C Surfanol 104-PG50 <30 3D Surfanol 2502 34-36 3E Dynol 604 32-34 3F Dynol 607 <30 - The base fluid may comprise hydrocarbons, such as C6-C20 hydrocarbons, and the gelling agent may comprise a gelling agent for hydrocarbons. The gelling agent may comprise a phosphate based chemical. In other cases the base fluid may be water, and the gelling agent may be a gelling agent for water. The base fluid may comprise liquefied petroleum gas, and the gelling agent may comprise a gelling agent for liquefied petroleum gas. LPG has been advantageously used as a fracturing fluid to simplify the recovery and clean-up of frac fluids after a frac. Exemplary LPG frac systems are disclosed in WO2007098606, incorporated herein by reference. One example of a suitable gelling agent for LPG is created by first reacting diphosphorous pentoxide with triethyl phosphate and an alcohol having hydrocarbon chains of 3-7 carbons long, or in a further for example alcohols having hydrocarbon chains 4-6 carbons long. The orthophosphate acid ester formed is then reacted with aluminum sulphate to create the desired gelling agent. The gelling agent created will have hydrocarbon chains from 3-7 carbons long or, as in the further example, 4-6 carbons long. The hydrocarbon chains of the gelling agent are thus commensurate in length with the hydrocarbon chains of liquid petroleum gas used for the frac fluid. This gelling agent is more effective at gelling a propane or butane fluid than a gelling agent with longer hydrocarbon chains. The proportion of gelling agent in the frac fluid is adjusted to obtain a suitable viscosity in the gelled frac fluid.
- In some embodiments, a volatile-phosphorus free gelling agent may be used, for example for gelling hydrocarbons. Such a gelling agent may have the general formula of:
- where X is an OR1, NR1R2, or SR1 group, R1 is an organic group having 2-24 carbon atoms, and R2 is an organic group or a hydrogen. Y is an NR3R4 or SR3 group, R3 is an organic group having 2-24 carbon atoms, and R4 is an organic group or a hydrogen. Such gelling agent may be made as follows. Phosphorus oxyhalide is reacted with a chemical reagent to produce substantially only diester phosphorus oxyhalide, the chemical reagent comprising at least one of an organic alcohol having 2-24 carbon atoms, an organic amine with an organic group having 2-24 carbon atoms, and an organic sulfide having 2-24 carbon atoms. The diester phosphorus oxyhalide is then hydrolyzed to produce diester phosphoric acid. Further examples are given in WO/2010/022496, incorporated herein by reference.
- LPG may include a variety of petroleum and natural gases existing in a liquid state at ambient temperatures and moderate pressures. In some cases, LPG refers to a mixture of such fluids. These mixes are generally more affordable and easier to obtain than any one individual LPG, since they are hard to separate and purify individually. Unlike conventional hydrocarbon based fracturing fluids, common LPGs are tightly fractionated products resulting in a high degree of purity and very predictable performance. Exemplary LPGs include ethane, propane, butane, or various mixtures thereof. As well, exemplary LPGs also include isomers of propane and butane, such as iso-butane. Further LPG examples include HD-5 propane, commercial butane, and n-butane. The LPG mixture may be controlled to gain the desired hydraulic fracturing and clean-up performance. LPG fluids used may also include minor amounts of pentane (such as i-pentane or n-pentane), and higher weight hydrocarbons.
- LPGs tend to produce excellent fracturing fluids. LPG is readily available, cost effective and is easily and safely handled on surface as a liquid under moderate pressure. LPG is completely compatible with formations and formation fluids, is highly soluble in formation hydrocarbons and eliminates phase trapping—resulting in increased well production. LPG may be readily and predictably viscosified to generate a fluid capable of efficient fracture creation and excellent proppant transport. After fracturing, LPG may be recovered very rapidly, allowing savings on clean up costs. In some embodiments, LPG may be predominantly propane, butane, or a mixture of propane and butane. In some embodiments, LPG may comprise more than 80%, 90%, or 95% propane, butane, or a mixture of propane and butane.
- Exemplary gelling agents that may be used are disclosed by Whitney in U.S. Pat. Nos. 3,775,069 and 3,846,310, the specifications of which are incorporated by reference. Such gelling agents may create water-sensitive gels. An example of a suitable gelling agent comprises a combination of an alkoxide of a group IIIA element and an alkoxide of an alkali metal. When combined, the alkoxide of the group IIIA element and the alkoxide of the alkali metal react to form a polymer gel. The group IIIA element may comprise one or more of boron and aluminum for example. In some embodiments, the alkoxide of a group IIIA element comprises M1(OR1)(OR2)(OR3), in which M1=the group IIIA element, and R1, R2, and R3 are organic groups. Each of the organic groups of R1, R2, and R3 may have 2-10 carbon atoms, and may comprise an alkyl group. In one embodiment, M1=boron, and R1, R2, and R3 comprise 2-10 carbon atoms. The alkali metal may comprise one or more of lithium, sodium, and potassium for example. In some embodiments, the alkoxide of an alkali metal further comprises M2(OR4), in which M2=the alkali metal, and R4 comprises an organic group. The organic group of R4 may comprise 2-24 carbon atoms, for further example 12 carbon atoms, and may comprise an alkyl group. In one embodiment, M2=lithium and the organic group of R4 comprises 2-24 carbon atoms. In some embodiments, R4 may further comprise: (AQ)n(R5)x(R6)y. in which A is an organic group, Q is O or N, n is 1-10, R5 and R6 are organic groups, x is either 1 or 2 depending on the valence of Q, and y is 0 or 1 depending on the valence of Q. Thus, the alkoxide of an alkali metal formed would have the formula of M2O(AQ)n(R5)x(R)y. A may have 2-4 carbon atoms. The organic groups of R5 and R6 may each have 1-16 carbons. Where y=1, R6 is bonded to the Q atom. Organic groups as disclosed herein may refer to groups with at least one carbon atom, as long the resulting gelling agent is suitable for its purpose. Examples of organic groups include phenyl, aryl, alkenyl, alkynyl, cyclo, and ether groups. A suitable amount of gelling agent may be used, for example 0.25-5% by weight of the fracturing fluid. In addition, the a suitable ration of the alkoxide of a group IIIA element and the alkoxide of an alkali metal may be used, for example 3:1 to 1:3, with 1:1 being a preferable ratio.
- The following exemplary procedure may be used to form a fracturing fluid containing a water sensitive gel as discussed in the preceding paragraph. Butyl lithium (3.53 mL of a 1.7 M solution in pentane, 6 mmol) was added dropwise to a stirring solution of dodecanol (1.12 g, 6 mmol) in pentane (125.00 g, 1% by wt gelling agents in pentane). This mixture was then stirred for a further 1 h at room temperature. A separate solution of tributyl borate (1.62 mL, 6 mmol) in pentane (125.00 g) was prepared in a blender at 17% variance with a rheostat for 5 min. To this solution was added the lithium alkoxide solution and a hydrated breaker, for example CaSO4(2H2O) (2.91 g, 0.15% by vol. H2O, 60 mesh) Blending was continued for 1 min at 30% variance. Over this time cloudy white gels formed. These were tested on a Brookfield viscometer-60° C., 4 h, 110 psi.
- Exemplary breakers for use with water-sensitive gels include hydrated breakers. For example, the hydrated breaker may comprise one or more hydrates, wherein water of the one or more hydrates is releasable so as to act with the water-sensitive carrier to reduce the viscosity of the fracturing fluid. A hydrated breaker may have a crystalline framework containing water that is bound within the crystalline framework and releasable into the fracturing fluid to act on the water-sensitive gel to reduce the viscosity of the fracturing fluid. Hydrated breakers are disclosed for example in U.S. application Ser. No. 12/609,893 and CA Application No. 2685298 the content of which is incorporated here by reference where permitted by law.
- In some embodiments, a gelling agent need not be specifically targeted by the surface energy reducing agent. For example, the surface energy reducing agent may be selected to effectively reduce the surface energy of the subterranean formation to at or below the surface tension of one or more of the base fluid, breaker, activator, gelling agent, or other treating chemical. Thus, the targeted injected chemicals may be easily removed after treatment is complete, and potential for well damage by tacky chemicals is reduced or eliminated.
- Various surfactants may be used as the surface energy reducing agent. For example, the surfactant may comprise one or more of an ionic surfactant and a non-ionic surfactant. For further example, if used the ionic surfactant may comprise one or more of an anionic surfactant, a cationic surfactant, and a zwitterionic surfactant.
- Anionic surfactants may be based on permanent anions such as sulfate, sulfonate, and phosphate, or pH-dependent anions such as carboxylate. Example anionic surfactants based on sulfates include alkyl sulfates such as ammonium lauryl sulfate and sodium lauryl sulfate (SDS), alkyl ether sulfates such as sodium laureth sulfate (also known as sodium lauryl ether sulfate or SLES), and sodium myreth sulfate. Example anionic surfactants based on sulfonates include docusates such as dioctyl sodium sulfosuccinate. Example anionic surfactants based on sulfonates also include sulfonate fluorosurfactants such as perfluorooctanesulfonate (PFOS), and perfluorobutanesulfonate. Example anionic surfactants based on sulfonates also include alkyl benzene sulfonates. Example anionic surfactants based on phosphates include alkyl aryl ether phosphate and alkyl ether phosphate. Example anionic surfactants based on carboxylates include alkyl carboxylates such as fatty acid salts (soaps) and sodium stearate. Example anionic surfactants based on carboxylates also include sodium lauroyl sarcosinate. Example anionic surfactants based on carboxylates also include carboxylate fluorosurfactants such as perfluorononanoate, and perfluorooctanoate (PFOA or PFO).
- Cationic surfactants may be based on pH-dependent amines or permanently charged quaternary ammonium cations. Example cationic surfactants based on pH-dependent amines include primary, secondary or tertiary amines. For example, primary amines may be used that become positively charged at pH<10, and secondary amines may be used that become charged at pH<4. One example of a pH-dependent amine is octenidine dihydrochloride. Example cationic surfactants based on permanently charged quaternary ammonium cations include alkyltrimethylammonium salts such as cetyl trimethylammonium bromide (CTAB a.k.a. hexadecyl trimethyl ammonium bromide), and cetyl trimethylammonium chloride (CTAC). Example cationic surfactants based on permanently charged quaternary ammonium cations also include cetylpyridinium chloride (CPC), polyethoxylated tallow amine (POEA), benzalkonium chloride (BAC), benzethonium chloride (BZT), 5-bromo-5-nitro-1,3-dioxane, dimethyldioctadecylammonium chloride, and dioctadecyldimethylammonium bromide (DODAB).
- Zwitterionic surfactants, which may be amphoteric, may be based on primary, secondary or tertiary amines or quaternary ammonium cations with sulfonate, carboxylate, or phosphate anions. Example zwitterionic surfactants with sulfonates include CHAPS (3-[(3-Cholamidopropyl)dimethylammonio]-1-propanesulfonate), and sultaines such as cocamidopropyl hydroxysultaine. Example zwitterionic surfactants with carboxylates include amino acids, imino acids, and betaines such as cocamidopropyl betaine. Example zwitterionic surfactants with phosphates include lecithin.
- Nonionic surfactants may include fatty alcohols such as cetyl alcohol, stearyl alcohol, cetostearyl alcohol (for example comprising predominantly of cetyl and stearyl alcohols), and oleyl alcohol. Nonionic surfactants may also include polyoxyethylene glycol alkyl ethers (Brij or CH3—(CH2)10-16—(O—C2H4)1-25—OH) such as octaethylene glycol monododecyl ether, and pentaethylene glycol monododecyl ether. Nonionic surfactants may also include polyoxypropylene glycol alkyl ethers (CH3—(CH2)10-16—(O—C3H6)1-25—OH). Nonionic surfactants may also include glucoside alkyl ethers (CH3—(CH2)10-16—(O-Glucoside)1-3-OH) such as decyl glucoside, lauryl glucoside, and octyl glucoside. Nonionic surfactants may also include polyoxyethylene glycol octylphenol ethers (C8H17—(C6H4)—(O—C2H4)1-25—OH) such as Triton X-100. Nonionic surfactants may also include polyoxyethylene glycol alkylphenol ethers (C9H19—(C6H4)—(O—C2H4)1-25—OH) such as nonoxynol-9. Nonionic surfactants may also include glycerol alkyl esters such as glyceryl laurate. Nonionic surfactants may also include polyoxyethylene glycol sorbitan alkyl esters such as polysorbates. Nonionic surfactants may also include sorbitan alkyl esters such as spans. Nonionic surfactants may also include cocamide MEA, and cocamide DEA. Nonionic surfactants may also include dodecyl dimethylamine oxide, and block copolymers of polyethylene glycol and polypropylene glycol such as poloxamers.
-
TABLE 3 Accudyne Test Results on non-ionic, anionic, and cationic surfactants in gelled LPG (LP10). Effective Surface Energy of Surfactant added Modified Formation 24 Sample1-hexadecanol (non-ionic) 34-36 Sodium dodecyl sulfate (anionic) 32-34 Benzalkonium Chloride (cationic) 38-40 - LP10 is a broken dialkyl phosphate LPG gel.
- In the claims, the word “comprising” is used in its inclusive sense and does not exclude other elements being present. The indefinite article “a” before a claim feature does not exclude more than one of the feature being present. Each one of the individual features described here may be used in one or more embodiments and is not, by virtue only of being described here, to be construed as essential to all embodiments as defined by the claims.
Claims (17)
1. A method of treating a subterranean formation containing hydrocarbons, the method comprising:
modifying the subterranean formation with a surface energy reducing agent; and
injecting into the subterranean formation a fracturing fluid containing a base fluid and a gelling agent;
in which the surface energy reducing agent is selected to effectively reduce the surface energy of the subterranean formation to at or below the surface tension of the gelling agent.
2. The method of claim 1 in which the surface energy reducing agent is selected such that the modified subterranean formation does not bond with the gelling agent.
3. The method of claim 1 in which the surface energy reducing agent adheres to the subterranean formation more strongly than the gelling agent adheres to the subterranean formation.
4. The method of claim 1 in which the surface energy reducing agent is selected to effectively reduce the net force of adhesion between the subterranean formation and the gelling agent (FFG) from above to below the net force of cohesion of the gelling agent (FGG).
5. The method of claim 1 further comprising breaking a gel, formed of the gelling agent, in the subterranean formation, in which the surface energy reducing agent is selected to effectively reduce the surface energy of the subterranean formation to at or below the surface tension of the gelling agent when broken.
6. The method of claim 1 in which modifying is carried out by injecting fracturing fluid comprising the surface energy reducing agent.
7. The method of claim 1 in which modifying comprises coating.
8. The method of claim 1 in which the surface energy reducing agent comprises a surfactant.
9. The method of claim 8 in which the surface energy reducing agent comprises an alkyne-diol.
10. The method of claim 8 in which the surface energy reducing agent comprises one or more of Surfanol MB, Surfanol 104-PG50, Surfanol 2502, Dynol 604, and Dynol 607.
11. The method of claim 8 in which the surfactant comprises one or more of an ionic surfactant and a non-ionic surfactant.
12. The method of claim 11 in which the ionic surfactant comprises one or more of an anionic surfactant, a cationic surfactant, and a zwitterionic surfactant.
13. The method of claim 1 in which the base fluid comprises hydrocarbons and the gelling agent comprises a gelling agent for hydrocarbons.
14. The method of claim 13 in which the gelling agent comprises a polyacrylimide.
15. The method of claim 1 in which the base fluid comprises liquefied petroleum gas.
16. The method of claim 15 in which the gelling agent comprises a gelling agent for liquefied petroleum gas.
17. The method of claim 1 in which the gelling agent is selected to have a surface tension of between twenty and forty-six dynes/cm when in the subterranean formation after breaking.
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- 2012-01-16 CA CA2764306A patent/CA2764306A1/en not_active Abandoned
- 2012-01-17 US US13/352,064 patent/US20120318514A1/en not_active Abandoned
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US9862881B2 (en) | 2015-05-13 | 2018-01-09 | Preferred Technology, Llc | Hydrophobic coating of particulates for enhanced well productivity |
US10577563B2 (en) | 2016-11-10 | 2020-03-03 | Refined Technologies, Inc. | Petroleum distillates with increased solvency |
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US11898431B2 (en) | 2020-09-29 | 2024-02-13 | Universal Chemical Solutions, Inc. | Methods and systems for treating hydraulically fractured formations |
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