CN113773821A - High-temperature blockage-regulating cleanup additive and preparation method and application thereof - Google Patents
High-temperature blockage-regulating cleanup additive and preparation method and application thereof Download PDFInfo
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- CN113773821A CN113773821A CN202010521040.6A CN202010521040A CN113773821A CN 113773821 A CN113773821 A CN 113773821A CN 202010521040 A CN202010521040 A CN 202010521040A CN 113773821 A CN113773821 A CN 113773821A
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- Prior art keywords
- temperature
- plugging
- cleanup additive
- sulfonate
- regulating
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- 239000000654 additive Substances 0.000 title claims abstract description 68
- 230000000996 additive effect Effects 0.000 title claims abstract description 67
- 238000002360 preparation method Methods 0.000 title claims abstract description 11
- 238000007599 discharging Methods 0.000 claims abstract description 26
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 25
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 21
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims abstract description 17
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims abstract description 17
- 239000004094 surface-active agent Substances 0.000 claims abstract description 16
- 239000000178 monomer Substances 0.000 claims abstract description 12
- 230000005465 channeling Effects 0.000 claims abstract description 11
- 239000003431 cross linking reagent Substances 0.000 claims abstract description 11
- 239000003999 initiator Substances 0.000 claims abstract description 9
- 239000000295 fuel oil Substances 0.000 claims abstract description 8
- 238000005516 engineering process Methods 0.000 claims abstract description 5
- 229910052799 carbon Inorganic materials 0.000 claims abstract description 4
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 21
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 16
- 238000000034 method Methods 0.000 claims description 11
- -1 alkyl naphthalene sulfonate Chemical compound 0.000 claims description 9
- 230000008569 process Effects 0.000 claims description 9
- 239000011837 N,N-methylenebisacrylamide Substances 0.000 claims description 8
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 8
- FUSUHKVFWTUUBE-UHFFFAOYSA-N buten-2-one Chemical compound CC(=O)C=C FUSUHKVFWTUUBE-UHFFFAOYSA-N 0.000 claims description 8
- 238000002156 mixing Methods 0.000 claims description 8
- ZIUHHBKFKCYYJD-UHFFFAOYSA-N n,n'-methylenebisacrylamide Chemical compound C=CC(=O)NCNC(=O)C=C ZIUHHBKFKCYYJD-UHFFFAOYSA-N 0.000 claims description 8
- OMNKZBIFPJNNIO-UHFFFAOYSA-N n-(2-methyl-4-oxopentan-2-yl)prop-2-enamide Chemical compound CC(=O)CC(C)(C)NC(=O)C=C OMNKZBIFPJNNIO-UHFFFAOYSA-N 0.000 claims description 7
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical compound [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 claims description 6
- 229910052708 sodium Inorganic materials 0.000 claims description 5
- 239000011734 sodium Substances 0.000 claims description 5
- 239000002351 wastewater Substances 0.000 claims description 5
- LCPVQAHEFVXVKT-UHFFFAOYSA-N 2-(2,4-difluorophenoxy)pyridin-3-amine Chemical compound NC1=CC=CN=C1OC1=CC=C(F)C=C1F LCPVQAHEFVXVKT-UHFFFAOYSA-N 0.000 claims description 4
- UFIOPCXETLAGLR-UHFFFAOYSA-N 2-acetyloxyethyl prop-2-enoate Chemical compound CC(=O)OCCOC(=O)C=C UFIOPCXETLAGLR-UHFFFAOYSA-N 0.000 claims description 4
- HGINCPLSRVDWNT-UHFFFAOYSA-N Acrolein Chemical compound C=CC=O HGINCPLSRVDWNT-UHFFFAOYSA-N 0.000 claims description 4
- STNJBCKSHOAVAJ-UHFFFAOYSA-N Methacrolein Chemical compound CC(=C)C=O STNJBCKSHOAVAJ-UHFFFAOYSA-N 0.000 claims description 4
- OFLXLNCGODUUOT-UHFFFAOYSA-N acetohydrazide Chemical compound C\C(O)=N\N OFLXLNCGODUUOT-UHFFFAOYSA-N 0.000 claims description 4
- 125000000217 alkyl group Chemical group 0.000 claims description 4
- 150000008052 alkyl sulfonates Chemical class 0.000 claims description 4
- VJRITMATACIYAF-UHFFFAOYSA-N benzenesulfonohydrazide Chemical compound NNS(=O)(=O)C1=CC=CC=C1 VJRITMATACIYAF-UHFFFAOYSA-N 0.000 claims description 4
- USHAGKDGDHPEEY-UHFFFAOYSA-L potassium persulfate Chemical compound [K+].[K+].[O-]S(=O)(=O)OOS([O-])(=O)=O USHAGKDGDHPEEY-UHFFFAOYSA-L 0.000 claims description 4
- 230000001105 regulatory effect Effects 0.000 claims description 4
- CHQMHPLRPQMAMX-UHFFFAOYSA-L sodium persulfate Substances [Na+].[Na+].[O-]S(=O)(=O)OOS([O-])(=O)=O CHQMHPLRPQMAMX-UHFFFAOYSA-L 0.000 claims description 4
- 239000004711 α-olefin Substances 0.000 claims description 4
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims description 3
- 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 claims description 3
- ZTJNPDLOIVDEEL-UHFFFAOYSA-N 2-acetyloxyethyl 2-methylprop-2-enoate Chemical compound CC(=C)C(=O)OCCOC(C)=O ZTJNPDLOIVDEEL-UHFFFAOYSA-N 0.000 claims description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 2
- 229920001732 Lignosulfonate Polymers 0.000 claims description 2
- 239000011575 calcium Substances 0.000 claims description 2
- 229910052791 calcium Inorganic materials 0.000 claims description 2
- 239000003002 pH adjusting agent Substances 0.000 claims description 2
- 239000003208 petroleum Substances 0.000 claims description 2
- KDYFGRWQOYBRFD-UHFFFAOYSA-L succinate(2-) Chemical compound [O-]C(=O)CCC([O-])=O KDYFGRWQOYBRFD-UHFFFAOYSA-L 0.000 claims description 2
- 239000002352 surface water Substances 0.000 claims description 2
- 239000008399 tap water Substances 0.000 claims description 2
- 235000020679 tap water Nutrition 0.000 claims description 2
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 claims 1
- 239000002253 acid Substances 0.000 claims 1
- 150000004996 alkyl benzenes Chemical class 0.000 claims 1
- 229940077388 benzenesulfonate Drugs 0.000 claims 1
- 230000003750 conditioning effect Effects 0.000 claims 1
- 238000010521 absorption reaction Methods 0.000 abstract description 3
- 239000003921 oil Substances 0.000 description 17
- 239000011435 rock Substances 0.000 description 14
- 230000015572 biosynthetic process Effects 0.000 description 10
- 239000010865 sewage Substances 0.000 description 10
- 239000010779 crude oil Substances 0.000 description 8
- 230000035699 permeability Effects 0.000 description 8
- 238000003756 stirring Methods 0.000 description 8
- BPSYZMLXRKCSJY-UHFFFAOYSA-N 1,3,2-dioxaphosphepan-2-ium 2-oxide Chemical compound O=[P+]1OCCCCO1 BPSYZMLXRKCSJY-UHFFFAOYSA-N 0.000 description 7
- ALWNROUGZXQZCX-UHFFFAOYSA-N [Ca].C=C Chemical group [Ca].C=C ALWNROUGZXQZCX-UHFFFAOYSA-N 0.000 description 6
- 238000002474 experimental method Methods 0.000 description 6
- 230000000694 effects Effects 0.000 description 5
- 238000002347 injection Methods 0.000 description 5
- 239000007924 injection Substances 0.000 description 5
- 239000007787 solid Substances 0.000 description 5
- 238000010793 Steam injection (oil industry) Methods 0.000 description 4
- IBVAQQYNSHJXBV-UHFFFAOYSA-N adipic acid dihydrazide Chemical compound NNC(=O)CCCCC(=O)NN IBVAQQYNSHJXBV-UHFFFAOYSA-N 0.000 description 4
- 230000008859 change Effects 0.000 description 4
- 239000000499 gel Substances 0.000 description 4
- 239000011148 porous material Substances 0.000 description 4
- 229920006395 saturated elastomer Polymers 0.000 description 4
- 238000004088 simulation Methods 0.000 description 4
- 229940120146 EDTMP Drugs 0.000 description 3
- PIICEJLVQHRZGT-UHFFFAOYSA-N Ethylenediamine Chemical compound NCCN PIICEJLVQHRZGT-UHFFFAOYSA-N 0.000 description 3
- ABLZXFCXXLZCGV-UHFFFAOYSA-N Phosphorous acid Chemical compound OP(O)=O ABLZXFCXXLZCGV-UHFFFAOYSA-N 0.000 description 3
- 230000009471 action Effects 0.000 description 3
- 229910052782 aluminium Inorganic materials 0.000 description 3
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 description 3
- 229920006037 cross link polymer Polymers 0.000 description 3
- 238000006297 dehydration reaction Methods 0.000 description 3
- NFDRPXJGHKJRLJ-UHFFFAOYSA-N edtmp Chemical compound OP(O)(=O)CN(CP(O)(O)=O)CCN(CP(O)(O)=O)CP(O)(O)=O NFDRPXJGHKJRLJ-UHFFFAOYSA-N 0.000 description 3
- 239000006260 foam Substances 0.000 description 3
- 239000007788 liquid Substances 0.000 description 3
- RGSFGYAAUTVSQA-UHFFFAOYSA-N pentamethylene Natural products C1CCCC1 RGSFGYAAUTVSQA-UHFFFAOYSA-N 0.000 description 3
- 125000004817 pentamethylene group Chemical group [H]C([H])([*:2])C([H])([H])C([H])([H])C([H])([H])C([H])([H])[*:1] 0.000 description 3
- 229920002401 polyacrylamide Polymers 0.000 description 3
- 229920000642 polymer Polymers 0.000 description 3
- 238000009991 scouring Methods 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 description 2
- ISWSIDIOOBJBQZ-UHFFFAOYSA-N Phenol Chemical compound OC1=CC=CC=C1 ISWSIDIOOBJBQZ-UHFFFAOYSA-N 0.000 description 2
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 description 2
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 description 2
- 238000010795 Steam Flooding Methods 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 2
- 229910052804 chromium Inorganic materials 0.000 description 2
- 239000011651 chromium Substances 0.000 description 2
- 229910001430 chromium ion Inorganic materials 0.000 description 2
- 238000004132 cross linking Methods 0.000 description 2
- 230000018044 dehydration Effects 0.000 description 2
- GVGUFUZHNYFZLC-UHFFFAOYSA-N dodecyl benzenesulfonate;sodium Chemical compound [Na].CCCCCCCCCCCCOS(=O)(=O)C1=CC=CC=C1 GVGUFUZHNYFZLC-UHFFFAOYSA-N 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 239000007863 gel particle Substances 0.000 description 2
- 230000036571 hydration Effects 0.000 description 2
- 238000006703 hydration reaction Methods 0.000 description 2
- 230000007774 longterm Effects 0.000 description 2
- WSFSSNUMVMOOMR-NJFSPNSNSA-N methanone Chemical compound O=[14CH2] WSFSSNUMVMOOMR-NJFSPNSNSA-N 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- 239000011347 resin Substances 0.000 description 2
- 229920005989 resin Polymers 0.000 description 2
- 230000002441 reversible effect Effects 0.000 description 2
- 238000009738 saturating Methods 0.000 description 2
- 229940080264 sodium dodecylbenzenesulfonate Drugs 0.000 description 2
- HEBRGEBJCIKEKX-UHFFFAOYSA-M sodium;2-hexadecylbenzenesulfonate Chemical compound [Na+].CCCCCCCCCCCCCCCCC1=CC=CC=C1S([O-])(=O)=O HEBRGEBJCIKEKX-UHFFFAOYSA-M 0.000 description 2
- 229920001187 thermosetting polymer Polymers 0.000 description 2
- 231100000419 toxicity Toxicity 0.000 description 2
- 230000001988 toxicity Effects 0.000 description 2
- 230000004580 weight loss Effects 0.000 description 2
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 1
- 230000002378 acidificating effect Effects 0.000 description 1
- 150000003926 acrylamides Chemical class 0.000 description 1
- 230000032683 aging Effects 0.000 description 1
- WNROFYMDJYEPJX-UHFFFAOYSA-K aluminium hydroxide Chemical compound [OH-].[OH-].[OH-].[Al+3] WNROFYMDJYEPJX-UHFFFAOYSA-K 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 239000002981 blocking agent Substances 0.000 description 1
- 230000037396 body weight Effects 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 238000010382 chemical cross-linking Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- JMGZBMRVDHKMKB-UHFFFAOYSA-L disodium;2-sulfobutanedioate Chemical compound [Na+].[Na+].OS(=O)(=O)C(C([O-])=O)CC([O-])=O JMGZBMRVDHKMKB-UHFFFAOYSA-L 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000004945 emulsification Methods 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- BEGBSFPALGFMJI-UHFFFAOYSA-N ethene;sodium Chemical group [Na].C=C BEGBSFPALGFMJI-UHFFFAOYSA-N 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 150000004676 glycans Chemical class 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- OAKJQQAXSVQMHS-UHFFFAOYSA-N hydrazine group Chemical group NN OAKJQQAXSVQMHS-UHFFFAOYSA-N 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 235000015110 jellies Nutrition 0.000 description 1
- 239000008274 jelly Substances 0.000 description 1
- 230000002045 lasting effect Effects 0.000 description 1
- 231100000053 low toxicity Toxicity 0.000 description 1
- 229910021645 metal ion Inorganic materials 0.000 description 1
- 239000008267 milk Substances 0.000 description 1
- 210000004080 milk Anatomy 0.000 description 1
- 235000013336 milk Nutrition 0.000 description 1
- 239000007764 o/w emulsion Substances 0.000 description 1
- 238000006116 polymerization reaction Methods 0.000 description 1
- 229920001282 polysaccharide Polymers 0.000 description 1
- 239000005017 polysaccharide Substances 0.000 description 1
- 239000002244 precipitate Substances 0.000 description 1
- 230000002265 prevention Effects 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 230000036632 reaction speed Effects 0.000 description 1
- 229910000029 sodium carbonate Inorganic materials 0.000 description 1
- 229940074404 sodium succinate Drugs 0.000 description 1
- ZDQYSKICYIVCPN-UHFFFAOYSA-L sodium succinate (anhydrous) Chemical compound [Na+].[Na+].[O-]C(=O)CCC([O-])=O ZDQYSKICYIVCPN-UHFFFAOYSA-L 0.000 description 1
- 230000006641 stabilisation Effects 0.000 description 1
- 238000011105 stabilization Methods 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
- 239000007762 w/o emulsion Substances 0.000 description 1
- 238000009736 wetting Methods 0.000 description 1
Classifications
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
-
- C—CHEMISTRY; METALLURGY
- C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
- C08F—MACROMOLECULAR COMPOUNDS OBTAINED BY REACTIONS ONLY INVOLVING CARBON-TO-CARBON UNSATURATED BONDS
- C08F220/00—Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and only one being terminated by only one carboxyl radical or a salt, anhydride ester, amide, imide or nitrile thereof
- C08F220/02—Monocarboxylic acids having less than ten carbon atoms; Derivatives thereof
- C08F220/52—Amides or imides
- C08F220/54—Amides, e.g. N,N-dimethylacrylamide or N-isopropylacrylamide
- C08F220/56—Acrylamide; Methacrylamide
-
- C—CHEMISTRY; METALLURGY
- C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
- C08F—MACROMOLECULAR COMPOUNDS OBTAINED BY REACTIONS ONLY INVOLVING CARBON-TO-CARBON UNSATURATED BONDS
- C08F222/00—Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and at least one being terminated by a carboxyl radical and containing at least one other carboxyl radical in the molecule; Salts, anhydrides, esters, amides, imides, or nitriles thereof
- C08F222/36—Amides or imides
- C08F222/38—Amides
- C08F222/385—Monomers containing two or more (meth)acrylamide groups, e.g. N,N'-methylenebisacrylamide
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- 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5083—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
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- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/592—Compositions used in combination with generated heat, e.g. by steam injection
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/602—Compositions for stimulating production by acting on the underground formation containing surfactants
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- 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
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/882—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
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- 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
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/887—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
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- Chemical & Material Sciences (AREA)
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- General Life Sciences & Earth Sciences (AREA)
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- Materials Engineering (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Health & Medical Sciences (AREA)
- Medicinal Chemistry (AREA)
- Polymers & Plastics (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Colloid Chemistry (AREA)
Abstract
The invention provides a high-temperature blockage-regulating cleanup additive, and a preparation method and application thereof. The high-temperature blockage-regulating cleanup additive comprises acrylamide and derivatives thereof, a ketonic-carbon-based monomer, a cross-linking agent, an initiator, a retarder, a sulfonate surfactant and water. The invention also provides a preparation method of the high-temperature blockage-regulating cleanup additive. The invention further provides the application of the high-temperature plugging and discharging assistant agent in a plugging and channeling adjusting technology of a heavy oil reservoir at the temperature of more than 200 ℃. The plugging rate of the high-temperature plugging and discharging assistant agent provided by the invention can reach more than 92%, the high-temperature plugging and discharging assistant agent can resist the temperature of 300 ℃, the effective period can reach more than 1 month under the steam condition of 250 ℃, and the plugging strength can reach 22 MPa/m; the high-temperature plugging and discharging assistant has good fluidity and temperature resistance, is simple to prepare, low in cost, adjustable in gelling time and strong in plugging capability, can enter deep parts of stratums, and effectively solves the problems of uneven steam absorption profile and steam channeling among wells of a common heavy oil well.
Description
Technical Field
The invention relates to the technical field of oilfield development, in particular to a high-temperature plugging-regulating cleanup additive and a preparation method and application thereof.
Background
With the increase of the huff and puff times of the thickened oil block of the Liaohe oil field, the formation pressure is low, the vacancy is serious, the steam channeling is prominent, the oil extraction speed is low, the thickened oil block is in a low-efficiency exploitation state and is influenced by various factors such as formation heterogeneity, the steam gravity is overlaped in the exploitation process, the steam absorption profile is uneven, the steam channeling among wells, heavy components of the crude oil in the formation are increased, the crude oil is emulsified in reverse phase, the oil flow channel is blocked, in addition, the formation energy is low, the flowback performance is poor, and the like, so that the thickened oil thermal recovery efficiency is seriously reduced, and the improvement of the recovery ratio is influenced.
At present, the gel water shutoff agent which is most widely applied is mainly a complex cross-linked polymer of Polyacrylamide (PAM) or polysaccharide and high-valence metal ions such as chromium, aluminum and the like, and a chemical cross-linked polymer of the complex cross-linked polymer and formaldehyde, phenol and the like. Because the original water of the continental-phase oil reservoir in China is mainly sodium carbonate, the aluminum cross-linking agent system is easy to decompose to generate aluminum hydroxide precipitate; compared with an aluminum crosslinking system, the organic chromium system has wider applicable conditions and high tolerance mineralization and temperature, however, chromium ions, particularly high-valence chromium ions, have very high lasting danger to the environment and do not meet the actual requirements of large-scale gel water plugging; the chemical cross-linking agents such as formaldehyde, phenol and the like are difficult to calculate accurately, inconvenient to transport, high in toxicity and harmful to the environment. The existing high-temperature profile control agent mainly comprises high-temperature organic gel, thermosetting resin, gel particle plugging agent, foam plugging agent and the like. Wherein the price of the high-temperature organic jelly is higher; the thermosetting resin has no selectivity, the curing speed is very sensitive to the temperature, and the controllability is poor; the gel particle plugging agent cannot be injected into the deep part of the stratum; the plugging strength of the foam water plugging agent is too low, and the stratum adaptability is poor.
Therefore, aiming at the current problems of safety and environmental protection, the high-temperature blockage regulating measures lack a chemical agent with low toxicity and low damage, can effectively block a hypertonic channel or a steam channeling channel, and can be quickly degraded after steam injection is finished, thereby playing a role of high-temperature blockage regulating and discharge aiding agent integrating milk prevention, emulsion breaking, viscosity reduction and flowback on the formation crude oil.
Disclosure of Invention
In order to solve the above problems, the present invention aims to provide a high temperature plugging and cleanup additive, and a preparation method and an application thereof. When the temperature of the stratum reaches more than 200 ℃, the high-temperature plugging and cleanup additive system provided by the invention can be gradually hydrated and release a high-temperature surfactant, so that a 'Jamin effect' is formed in the stratum, and the effects of performing secondary profile control and expanding steam swept volume are achieved.
In order to achieve the above object, the present invention provides a high temperature plugging and cleanup additive, wherein the high temperature plugging and cleanup additive comprises, based on 100% of the total mass of the high temperature plugging and cleanup additive: 0.2-0.5% of acrylamide and derivatives thereof, 0.1-0.4% of ketonic-based monomer, 0.15-0.3% of cross-linking agent, 0.1-0.6% of initiator, 0.4-1% of retarder, 0.2-1% of sulfonate surfactant and the balance of water.
In the high-temperature plugging and discharging assistant, the acrylamide and the derivatives thereof can be used as the molecular structure of a gel-forming framework and polymerized to form a gel-forming system; under the action of steam, the polymer molecular chain of the gel-forming skeleton is broken, so that the organic components of the high-temperature plugging and discharging assistant are degraded and hydrated. Preferably, the acrylamide and its derivatives include acrylamide and/or N, N-methylenebisacrylamide.
In the high-temperature blockage and cleanup additive, the ketocarbonyl monomer (such as diacetone acrylamide) is low in toxicity and harmless to the environment, can introduce ketocarbonyl to a polymer chain formed by acrylamide and derivatives thereof, and is safe and environment-friendly. Preferably, the ketocarbon based monomer comprises one or a combination of two or more of diacetone acrylamide, acrolein, methacrolein, methyl vinyl ketone, acetoxyethyl acrylate, and acetoxyethyl methacrylate.
In the high-temperature plugging and discharging assistant, a polymer which is formed by a cross-linking agent containing a hydrazine group, polyacrylamide and derivatives thereof and has a ketone carbonyl group can be subjected to dehydration reaction under an acidic condition to generate a hydrazone compound, so that the high-temperature plugging and discharging assistant is cross-linked at a room temperature, and the gelling strength and the temperature resistance of the high-temperature plugging and discharging assistant are improved. Preferably, the cross-linking agent comprises one or a combination of more than two of acethydrazide, adihydrazide, N-diacetylhydrazide and benzenesulfonylhydrazide.
In the high-temperature plugging and cleanup additive, the initiator is used for catalyzing the polymerization reaction of the ketocarbon-based monomer and the acrylamide derivative monomer. Preferably, the initiator comprises one or a combination of two or more of ammonium persulfate, sodium persulfate and potassium persulfate.
In the high-temperature blockage and drainage-assisting agent, the sulfonate surfactant is used as a high-temperature surfactant, and the solution of the sulfonate surfactant can effectively strip an oil film on the surface of a rock, change the wettability of a stratum and prevent steam condensate water and thickened oil from forming a water-in-oil emulsion. Meanwhile, the surfactant, the condensed water and the thickened oil can form a good oil-in-water emulsion, so that the viscosity of the thickened oil is greatly reduced, the mobility of formation fluid is improved, and the effects of preventing emulsification, demulsifying, reducing viscosity and assisting drainage are achieved. Preferably, the sulfonate-type surfactant includes one or a combination of two or more of alkylbenzene sulfonate, α -olefin sulfonate, alkyl sulfonate, succinate sulfonate, alkyl naphthalene sulfonate, petroleum sulfonate, lignin sulfonate, and alkyl glyceryl ether sulfonate; more preferably, the alkyl group of the alkylbenzene sulfonate and/or the alkyl group of the alkyl sulfonate has a carbon number of 12 to 16.
In the high-temperature blockage and discharge assistant, the retarder is used for reducing the crosslinking reaction speed of the ketonic-carbon-based monomer and the acrylamide and the derivative thereof. Preferably, the retarder comprises one or a combination of more than two of ethylene diamine tetra methylene phosphonic acid calcium, ethylene diamine tetra methylene phosphonic acid sodium and ethylene diamine pentamethylene phosphonic acid.
According to particular embodiments of the invention, the water may include one or a combination of two or more of tap water, surface water, shallow water, and oilfield reinjection wastewater, preferably oilfield reinjection wastewater. In some embodiments, oilfield reinjection of wastewater above 20 ℃ may be employed.
According to a specific embodiment of the invention, the pH of the high temperature plugging and cleanup additive is generally controlled to be 5 to 7. In some embodiments, the pH of the high temperature plugging drainage aid may be adjusted using a pH adjuster, which preferably includes sodium hydroxide and/or potassium hydroxide.
According to the embodiment of the invention, the high-temperature plugging-adjusting cleanup additive can be applied to various oil wells, particularly thick oil wells.
The invention also provides a preparation method of the high-temperature blockage-regulating cleanup additive, wherein the preparation method comprises the following steps: adding acrylamide and derivatives thereof, a ketonic-based monomer, a cross-linking agent, an initiator, a retarder and a sulfonate surfactant into water, and mixing to obtain the high-temperature blockage-regulating cleanup additive.
According to a specific embodiment of the present invention, the preparation method of the high-temperature plugging and cleanup additive preferably comprises: the high-temperature plugging and discharging assistant is prepared by adding acrylamide and derivatives thereof, a ketonic-based monomer, a retarder and a sulfonate surfactant into water, stirring, adding a cross-linking agent and an initiator, and mixing. The stirring condition can be controlled to be 50-200r/min and the stirring time is controlled to be 20-30 min.
The invention further provides the application of the high-temperature plugging and discharging assistant agent in a plugging and channeling adjusting technology of a heavy oil reservoir at the temperature of more than 200 ℃. In the specific embodiment of the invention, the high-temperature plugging and discharging assistant agent can be suitable for plugging and channeling adjusting technologies of heavy oil reservoirs such as steam flooding, steam stimulation, SAGD and the like. For example, the method is applied to the plugging and channeling regulating technology of heavy oil reservoirs at 200-300 ℃.
The beneficial effects of the invention include:
1. the plugging rate of the high-temperature plugging and discharging assistant provided by the invention can reach more than 92%, the temperature can be up to 300 ℃, the effective period can reach more than 1 month under the condition of steam at 250 ℃, and the plugging strength can reach 22 MPa/m.
2. The high-temperature plugging and discharging assistant has the characteristics of good fluidity, temperature resistance, simple preparation, low cost and the like, has adjustable gelling time and strong plugging capability, is suitable for wide oil reservoir types, is not easy to pollute stratum, can enter deep part of the stratum, and effectively solves the problems of uneven steam absorption profile and steam channeling among wells of the common heavy oil well.
3. In the plugging control construction, along with the prolonging of steam injection time, when the temperature of a stratum reaches more than 200 ℃, the system of the high-temperature plugging control cleanup additive is gradually hydrated to release a high-temperature surfactant, and the surfactant can form a good foam system under the action of steam and steam condensate water, so that a 'Jamin effect' is formed in the stratum to play a role in secondary profile control, the trend of the steam is controlled and changed, and the steam swept volume is enlarged.
Detailed Description
The technical solutions of the present invention will be described in detail below in order to clearly understand the technical features, objects, and advantages of the present invention, but the present invention is not limited to the practical scope of the present invention.
Example 1
The embodiment provides a high-temperature blockage-regulating cleanup additive, which is prepared by the following processes:
1. by taking the total mass of the high-temperature plugging and discharging assistant as 100 percent, 0.2 percent of acrylamide, 0.1 percent of diacetone acrylamide, 0.15 percent of acethydrazide, 0.1 percent of ammonium persulfate, 0.4 percent of calcium ethylene diamine tetramethylene phosphonate, 0.2 percent of sodium dodecyl benzene sulfonate and the balance of oil field reinjection sewage are weighed.
2. Adding weighed acrylamide, diacetone acrylamide, acethydrazide, ammonium persulfate, calcium ethylene diamine tetramethylene phosphonate and sodium dodecyl benzene sulfonate into oil field reinjection sewage, adjusting the pH value to 5 by using sodium hydroxide, and stirring and mixing uniformly to obtain the high-temperature plugging and discharging assistant.
Example 2
The embodiment provides a high-temperature blockage-regulating cleanup additive, which is prepared by the following processes:
1. by taking the total mass of the high-temperature plugging and cleanup additive as 100 percent, 0.5 percent of N, N-methylene bisacrylamide, 0.4 percent of diacetone acrylamide, 0.3 percent of adipic dihydrazide, 0.6 percent of sodium persulfate, 1 percent of ethylene diamine tetramethylene phosphonic acid sodium, 1 percent of alpha-olefin sodium sulfonate and the balance of oilfield reinjection sewage are weighed.
2. Adding the weighed N, N-methylene bisacrylamide, diacetone acrylamide, adipic dihydrazide, sodium persulfate, sodium ethylene diamine tetramethylene phosphonate and alpha-olefin sodium sulfonate into the oilfield reinjection sewage, adjusting the pH value to 7 by using sodium hydroxide, and stirring and mixing uniformly to obtain the high-temperature plugging and cleanup additive.
Example 3
The embodiment provides a high-temperature blockage-regulating cleanup additive, which is prepared by the following processes:
1. based on the total mass of the high-temperature plugging and cleanup additive being 100%, 0.3% of N, N-methylene bisacrylamide, 0.2% of methacrolein, 0.2% of N, N-diacetyl hydrazide, 0.4% of potassium persulfate, 0.8% of ethylenediamine pentamethylene phosphonic acid, 0.6% of sodium hexadecyl benzene sulfonate and the balance of oilfield reinjection sewage are weighed.
2. Adding the weighed N, N-methylene bisacrylamide, methacrolein, N-diacetyl hydrazine, potassium persulfate, ethylenediamine pentamethylene phosphonic acid and sodium hexadecylbenzene sulfonate into the oil field reinjection sewage, adjusting the pH value to 6 by using sodium hydroxide, and stirring and mixing uniformly to obtain the high-temperature plugging and cleanup additive.
Example 4
The embodiment provides a high-temperature blockage-regulating cleanup additive, which is prepared by the following processes:
1. by taking the total mass of the high-temperature plugging and cleanup additive as 100 percent, 0.4 percent of acrylamide, 0.35 percent of methyl vinyl ketone, 0.25 percent of benzenesulfonyl hydrazide, 0.5 percent of ammonium persulfate, 0.6 percent of calcium ethylene diamine tetramethylene phosphonate, 0.8 percent of sodium sulfosuccinate and the balance of oilfield reinjection sewage are weighed.
2. Adding the weighed acrylamide, methyl vinyl ketone, benzenesulfonyl hydrazide, ammonium persulfate, calcium ethylene diamine tetramethylene phosphonate and sodium succinate sulfonate into the oilfield reinjection sewage, adjusting the pH value to 6 by using sodium hydroxide, and uniformly stirring and mixing to obtain the high-temperature plugging and discharging assistant.
Example 5
The embodiment provides a high-temperature blockage-regulating cleanup additive, which is prepared by the following processes:
1. based on the total mass of the high-temperature plugging and cleanup additive being 100%, 0.3% of N, N-methylene bisacrylamide, 0.2% of acetoxyethyl acrylate, 0.2% of adipic dihydrazide, 0.25% of ammonium persulfate, 0.5% of calcium ethylene diamine tetramethylene phosphonate, 0.5% of sodium dodecyl sulfate and the balance of oilfield reinjection sewage are weighed.
2. Adding the weighed N, N-methylene bisacrylamide, acetoxyethyl acrylate, adipic dihydrazide, ammonium persulfate, calcium ethylene diamine tetramethylene phosphonate and sodium dodecyl sulfate into the oilfield reinjection sewage, adjusting the pH value to 5 by using sodium hydroxide, and stirring and mixing uniformly to obtain the high-temperature plugging and drainage-assisting agent.
Test example 1
The test example provides a core single tube simulation experiment on the high-temperature plugging and cleanup additive of example 2, and is used for inspecting the permeability change condition of the core before and after being treated by the high-temperature plugging and cleanup additive. The specific process of the simulation experiment is as follows: the method comprises the steps of vacuumizing saturated water of a rock core, measuring the permeability of the rock core before plugging under a certain pump displacement, injecting a certain amount of high-temperature plugging and cleanup additive into the rock core in a forward direction until the rock core is saturated, placing the rock core injected with the high-temperature plugging and cleanup additive into a water bath at 80 ℃, and measuring the permeability of the rock core after plugging in a reverse direction after a period of time.
The relevant experimental parameters and the plugging strength properties of the high temperature plugging and cleanup additive are summarized in table 1.
TABLE 1
The results in table 1 show that the high-temperature plugging and cleanup additive provided by the invention has very strong formation plugging capability, and the effective plugging rate can reach more than 92%.
Test example 2
The test example providesThe single-tube model core experiment of the high-temperature plugging and cleanup additive prepared in example 2 is carried out to investigate the steam scouring resistance. The experimental parameters were: the core length is 5.5cm, and the core permeability is 1418 multiplied by 10-3μm2Core pore volume 11.5cm3The mass of injected steam is 115g (10PV), the injection temperature is 250 ℃, the injection flow is 2g/min, and the high-temperature plugging and cleanup additive is injected until the core is saturated. Table 2 summarizes the plugging rates for different steam injection times.
TABLE 2
Time of steam injection, min | 5 | 10 | 20 | 30 | 40 | 50 | 60 |
Plugging rate% | 95.4 | 93.6 | 91.4 | 88.7 | 82.4 | 78.6 | 73.5 |
From the results in table 2, it can be seen that as the steam scouring time is prolonged, the plugging rate of the high-temperature plugging and discharging assistant agent is reduced, which indicates that the gel-forming structure of the high-temperature plugging and discharging assistant agent is damaged, and finally the formed aqueous solution is discharged. When the volume of injected steam is 10PV, the plugging rate of the high-temperature plugging and cleanup additive to the rock core is kept at about 70%, which shows that the high-temperature plugging and cleanup additive has very strong steam scouring resistance, and simultaneously shows that the high-temperature plugging and cleanup additive can be degraded under the action of high temperature, thereby restoring the permeability of the stratum.
Test example 3
In the test example, a core single tube simulation experiment was performed on the high-temperature plugging and cleanup additive of example 3, and the breakthrough pressure of the high-temperature plugging and cleanup additive was measured to evaluate the plugging strength of the high-temperature plugging and cleanup additive on the formation. The plugging strength of the high-temperature plugging and cleanup additive can be evaluated by breakthrough pressure.
The test process of the core single tube simulation experiment is as follows:
(1) saturating the core with water;
(2) injecting 1PV high-temperature plugging and cleanup additive at a flow rate of 10ml/min, and setting conditions of external pressure of 20MPa and constant-temperature water bath at 80 ℃;
(3) placing the rock core injected with the high-temperature plugging and cleanup additive in a closed container, and placing the rock core in a water bath at 80 ℃;
(4) keeping the temperature and the external pressure of the water bath, injecting water at the flow rate of 15ml/min until the first drop of liquid flows down from the outlet end of the core holder and then the liquid continuously flows out, and recording the reading of a pressure gauge at the inlet end at the moment as the breakthrough pressure P of the high-temperature plugging and cleanup additivet. The permeability of the core No. 2019-14 is 684X 10-3μm2Pore volume 9.5cm3(ii) a 2019-15 core had a permeability of 735X 10-3μm2Pore volume 9.7cm3. Table 3 summarizes the results of the blocking strength test of the high temperature blocking and cleanup additive.
TABLE 3
Core numbering | Length (cm) | Injection blocking agent (PV) | Liquid outlet pressure (MPa) | Breakthrough pressure (MPa/m) |
2019-14 | 5.2 | 1 | 1.18 | 22.7 |
2019-15 | 5.5 | 1 | 1.21 | 22.0 |
As can be seen from Table 3, the plugging strength of the high-temperature plugging and cleanup additive provided in example 3 reaches 22MPa/m, meets the requirements of high-temperature plugging of steam flooding and huff-puff wells, has very high plugging capability, and can effectively avoid steam channeling.
Test example 4
The test example provides a high-temperature aging test of the high-temperature plugging and discharging assistant agent so as to investigate the temperature resistance of the high-temperature plugging and discharging assistant agent. The test procedure was as follows:
the high-temperature plugging and discharging assistant prepared in example 4 was allowed to stand for 24 hours until completely coagulated, and then placed in a thermostat, the temperature of the thermostat was adjusted every 24 hours, the weight loss rate of the high-temperature plugging and discharging assistant under different temperature conditions was tested, and the experimental results are summarized in table 4.
TABLE 4
Temperature of | 100 | 150 | 200 | 250 | 300 |
Status of state | Solid body | Solid body | Solid body | Solid body | Solid body |
Weight loss ratio (%) | 0 | 0 | 1.5 | 9.7 | 55.2 |
As can be seen from table 4, the weight loss rate of the high-temperature plugging and cleanup additive provided in example 4 increases with the increase of temperature, and when the temperature exceeds 200 ℃, the structure of the high-temperature plugging and cleanup additive changes, and high-temperature hydration starts to occur. The test result shows that the high-temperature plugging and cleanup additive can resist the high temperature of more than 200 ℃, has good high-temperature resistance, and can adapt to the application conditions of developing oil reservoirs by using steam to huff and puff heavy oil in China.
Test example 5
The test example is a high-temperature long-term stability experiment carried out on the high-temperature blockage-adjusting discharge-assisting agent, and the influence of a high-temperature environment on the long-term stability of the high-temperature blockage-adjusting discharge-assisting agent is examined. The experimental temperature was 250 ℃, the change in the dehydration rate over time of the high temperature plugging and cleanup additive prepared in example 5 was recorded, and the experimental results are summarized in table 5.
TABLE 5
Stabilization time of day | 1 | 3 | 7 | 10 | 15 | 21 | 30 | 45 |
A rate of dehydration% | 9.7 | 13.2 | 18.5 | 24.6 | 29.8 | 34.5 | 41.2 | 48.3 |
As can be seen from Table 5, the high temperature plugging and discharging assistant can maintain strong plugging for more than 1 month for a long time under the condition of 250 ℃.
Test example 6
The test example provides a single-tube model core experiment of the high-temperature plugging and drainage aid, and the experiment takes hydrate removed after the high-temperature stability experiment of test example 5 (namely hydrate stabilized at 250 ℃ for 45 days) as a sample, and inspects the stripping and wetting effects of the hydrated high-temperature plugging and drainage aid on crude oil of stratum rocks. The experimental procedure was as follows:
(1) saturating the crude oil in the rock core, introducing saturated water into the rock core, and displacing until no crude oil flows out;
(2) injecting hydrate of the 2PV high-temperature plugging and drainage assistant;
(3) the volume of displaced crude oil was measured at the outlet end using a graduated cylinder and the test results are summarized in table 6.
The experimental parameters were: the core length is 5.2cm, and the core permeability is 857 multiplied by 10-3μm2Pore volume 6.5cm3And injecting hydrate mass: 13g (2PV), injection flow rate: 2 g/min.
TABLE 6
Injection volume, PV | 0.2 | 0.5 | 1 | 1.5 | 2 |
Volume of crude oil, ml | 1.5 | 2.4 | 3.7 | 3.9 | 4.0 |
From table 6, it can be seen that the solution of the high-temperature surfactant released by the gradual hydration of the gel system of the high-temperature plugging and cleanup additive can effectively strip the oil film on the surface of the rock, change the wettability of the formation, improve the fluidity of the formation fluid, and perform the functions of viscosity reduction and cleanup.
Claims (10)
1. The high-temperature blockage-regulating cleanup additive comprises the following components in percentage by mass based on 100% of the total mass of the high-temperature blockage-regulating cleanup additive:
0.2-0.5% of acrylamide and derivatives thereof, 0.1-0.4% of ketonic-based monomer, 0.15-0.3% of cross-linking agent, 0.1-0.6% of initiator, 0.4-1% of retarder, 0.2-1% of sulfonate surfactant and the balance of water.
2. The high temperature plugging and cleanup additive of claim 1, wherein said acrylamide and its derivatives comprise acrylamide and/or N, N-methylenebisacrylamide.
3. The high temperature conditioning block and cleanup additive of claim 1, wherein the ketocarbon based monomer comprises one or a combination of two or more of diacetone acrylamide, acrolein, methacrolein, methyl vinyl ketone, acetoxyethyl acrylate, and acetoxyethyl methacrylate.
4. A high temperature plugging and cleanup additive according to any one of claims 1-3, wherein said cross-linking agent comprises one or a combination of two or more of acetohydrazide, adihydrazide, N-diacetylhydrazide, and benzenesulfonylhydrazide;
the initiator comprises one or the combination of more than two of ammonium persulfate, sodium persulfate and potassium persulfate.
5. The high temperature plugging and cleanup additive of claim 1, wherein the retarder comprises one or a combination of two or more of calcium ethylenediaminetetramethylenephosphonate, sodium ethylenediaminetetramethylenephosphonate, and ethylenediaminepentamethylenephosphonic acid.
6. The high temperature plugging and cleanup additive of claim 1, wherein the sulfonate-type surfactant comprises one or a combination of two or more of alkyl benzene sulfonate, alpha-olefin sulfonate, alkyl sulfonate, succinate sulfonate, alkyl naphthalene sulfonate, petroleum sulfonate, lignin sulfonate, and alkyl glycerol ether sulfonate;
preferably, the alkyl group of the alkylbenzene sulfonate and/or the alkyl group of the alkyl sulfonate has a carbon number of 12 to 16.
7. The high-temperature plugging and discharging assistant according to claim 1, wherein the water comprises one or more of tap water, surface water, shallow water and oilfield reinjection wastewater, preferably oilfield reinjection wastewater.
8. The high temperature plugging and cleanup additive of claim 1, wherein the cleanup additive has a pH of 5-7;
preferably, a pH value regulator is adopted to regulate the pH value of the high-temperature plugging and cleanup additive;
more preferably, the pH adjuster comprises sodium hydroxide and/or potassium hydroxide.
9. A process for the preparation of a high temperature plugging and cleanup additive as recited in any one of claims 1-8, comprising:
adding acrylamide and derivatives thereof, a ketonic-based monomer, a cross-linking agent, an initiator, a retarder and a sulfonate surfactant into water, and mixing to obtain the high-temperature blockage-regulating cleanup additive.
10. The use of the high-temperature plugging and cleanup additive as defined in any one of claims 1 to 8 in a plugging and channeling regulating technology for heavy oil reservoirs at a temperature of 200 ℃ or higher;
preferably, the application temperature of the high-temperature plugging and discharging assistant agent is 200-300 ℃.
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