CN116622359A - Self-assembled gel foam oil displacement agent suitable for high-temperature high-salt fracture-cavity oil reservoir and preparation method thereof - Google Patents
Self-assembled gel foam oil displacement agent suitable for high-temperature high-salt fracture-cavity oil reservoir and preparation method thereof Download PDFInfo
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- 239000006260 foam Substances 0.000 title claims abstract description 72
- 238000006073 displacement reaction Methods 0.000 title claims abstract description 47
- 238000002360 preparation method Methods 0.000 title claims abstract description 12
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 47
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 43
- 239000004094 surface-active agent Substances 0.000 claims abstract description 30
- 229920001577 copolymer Polymers 0.000 claims abstract description 28
- KWIUHFFTVRNATP-UHFFFAOYSA-N glycine betaine Chemical compound C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 claims abstract description 22
- 230000002209 hydrophobic effect Effects 0.000 claims abstract description 22
- -1 ion compound Chemical class 0.000 claims abstract description 19
- 229960003237 betaine Drugs 0.000 claims abstract description 18
- 150000001412 amines Chemical class 0.000 claims abstract description 12
- 150000008065 acid anhydrides Chemical class 0.000 claims abstract description 11
- 239000007788 liquid Substances 0.000 claims abstract description 11
- 150000007519 polyprotic acids Polymers 0.000 claims abstract description 11
- 239000002738 chelating agent Substances 0.000 claims abstract description 9
- 229910017053 inorganic salt Inorganic materials 0.000 claims abstract description 5
- 239000002994 raw material Substances 0.000 claims abstract description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 36
- 229910052757 nitrogen Inorganic materials 0.000 claims description 18
- 239000000243 solution Substances 0.000 claims description 18
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 15
- 238000003756 stirring Methods 0.000 claims description 15
- 150000003839 salts Chemical class 0.000 claims description 11
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 claims description 10
- 239000002244 precipitate Substances 0.000 claims description 10
- XLPJNCYCZORXHG-UHFFFAOYSA-N 1-morpholin-4-ylprop-2-en-1-one Chemical compound C=CC(=O)N1CCOCC1 XLPJNCYCZORXHG-UHFFFAOYSA-N 0.000 claims description 9
- ABBQHOQBGMUPJH-UHFFFAOYSA-M Sodium salicylate Chemical compound [Na+].OC1=CC=CC=C1C([O-])=O ABBQHOQBGMUPJH-UHFFFAOYSA-M 0.000 claims description 9
- 239000000693 micelle Substances 0.000 claims description 9
- 239000012966 redox initiator Substances 0.000 claims description 9
- 229960004025 sodium salicylate Drugs 0.000 claims description 9
- XFTALRAZSCGSKN-UHFFFAOYSA-M sodium;4-ethenylbenzenesulfonate Chemical compound [Na+].[O-]S(=O)(=O)C1=CC=C(C=C)C=C1 XFTALRAZSCGSKN-UHFFFAOYSA-M 0.000 claims description 9
- 239000011734 sodium Substances 0.000 claims description 8
- 229910052708 sodium Inorganic materials 0.000 claims description 8
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 8
- 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 7
- 239000003945 anionic surfactant Substances 0.000 claims description 7
- 239000001294 propane Substances 0.000 claims description 7
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonium chloride Substances [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims description 6
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical group [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 claims description 6
- 235000019270 ammonium chloride Nutrition 0.000 claims description 6
- 238000001035 drying Methods 0.000 claims description 5
- 238000010438 heat treatment Methods 0.000 claims description 5
- 239000011259 mixed solution Substances 0.000 claims description 5
- WBHQBSYUUJJSRZ-UHFFFAOYSA-M sodium bisulfate Chemical compound [Na+].OS([O-])(=O)=O WBHQBSYUUJJSRZ-UHFFFAOYSA-M 0.000 claims description 5
- 229910000342 sodium bisulfate Inorganic materials 0.000 claims description 5
- TWRXJAOTZQYOKJ-UHFFFAOYSA-L Magnesium chloride Chemical compound [Mg+2].[Cl-].[Cl-] TWRXJAOTZQYOKJ-UHFFFAOYSA-L 0.000 claims description 4
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims description 4
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 4
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 4
- LSNNMFCWUKXFEE-UHFFFAOYSA-M Bisulfite Chemical compound OS([O-])=O LSNNMFCWUKXFEE-UHFFFAOYSA-M 0.000 claims description 3
- 230000009471 action Effects 0.000 claims description 3
- JRKICGRDRMAZLK-UHFFFAOYSA-L persulfate group Chemical group S(=O)(=O)([O-])OOS(=O)(=O)[O-] JRKICGRDRMAZLK-UHFFFAOYSA-L 0.000 claims description 3
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 claims description 2
- KCXVZYZYPLLWCC-UHFFFAOYSA-N EDTA Chemical group OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O KCXVZYZYPLLWCC-UHFFFAOYSA-N 0.000 claims description 2
- PMZURENOXWZQFD-UHFFFAOYSA-L Sodium Sulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=O PMZURENOXWZQFD-UHFFFAOYSA-L 0.000 claims description 2
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 2
- 239000001110 calcium chloride Substances 0.000 claims description 2
- 229910001628 calcium chloride Inorganic materials 0.000 claims description 2
- 239000003054 catalyst Substances 0.000 claims description 2
- 239000012295 chemical reaction liquid Substances 0.000 claims description 2
- 238000007334 copolymerization reaction Methods 0.000 claims description 2
- SYELZBGXAIXKHU-UHFFFAOYSA-N dodecyldimethylamine N-oxide Chemical compound CCCCCCCCCCCC[N+](C)(C)[O-] SYELZBGXAIXKHU-UHFFFAOYSA-N 0.000 claims description 2
- 239000003999 initiator Substances 0.000 claims description 2
- 229910001629 magnesium chloride Inorganic materials 0.000 claims description 2
- IBOBFGGLRNWLIL-UHFFFAOYSA-N n,n-dimethylhexadecan-1-amine oxide Chemical compound CCCCCCCCCCCCCCCC[N+](C)(C)[O-] IBOBFGGLRNWLIL-UHFFFAOYSA-N 0.000 claims description 2
- 239000001301 oxygen Substances 0.000 claims description 2
- 229910052760 oxygen Inorganic materials 0.000 claims description 2
- 239000001103 potassium chloride Substances 0.000 claims description 2
- 235000011164 potassium chloride Nutrition 0.000 claims description 2
- 125000006160 pyromellitic dianhydride group Chemical group 0.000 claims description 2
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 2
- 239000011780 sodium chloride Substances 0.000 claims description 2
- 229910052938 sodium sulfate Inorganic materials 0.000 claims description 2
- 235000011152 sodium sulphate Nutrition 0.000 claims description 2
- 239000003921 oil Substances 0.000 abstract description 67
- 238000011084 recovery Methods 0.000 abstract description 15
- 238000005187 foaming Methods 0.000 abstract description 10
- 239000010779 crude oil Substances 0.000 abstract description 9
- 230000005514 two-phase flow Effects 0.000 abstract description 2
- 238000005406 washing Methods 0.000 abstract description 2
- 208000010392 Bone Fractures Diseases 0.000 description 18
- 206010017076 Fracture Diseases 0.000 description 18
- KWIUHFFTVRNATP-UHFFFAOYSA-O N,N,N-trimethylglycinium Chemical compound C[N+](C)(C)CC(O)=O KWIUHFFTVRNATP-UHFFFAOYSA-O 0.000 description 14
- 229920000642 polymer Polymers 0.000 description 14
- 239000000178 monomer Substances 0.000 description 9
- 230000000694 effects Effects 0.000 description 7
- 238000002474 experimental method Methods 0.000 description 7
- 239000007789 gas Substances 0.000 description 6
- 239000007924 injection Substances 0.000 description 6
- 238000002347 injection Methods 0.000 description 6
- 238000000034 method Methods 0.000 description 6
- 239000011435 rock Substances 0.000 description 6
- 238000012360 testing method Methods 0.000 description 6
- VLDPXPPHXDGHEW-UHFFFAOYSA-N 1-chloro-2-dichlorophosphoryloxybenzene Chemical compound ClC1=CC=CC=C1OP(Cl)(Cl)=O VLDPXPPHXDGHEW-UHFFFAOYSA-N 0.000 description 5
- 230000033558 biomineral tissue development Effects 0.000 description 4
- 239000002131 composite material Substances 0.000 description 4
- 238000011161 development Methods 0.000 description 4
- 230000018109 developmental process Effects 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 4
- PQBMXAQBYJCLST-UHFFFAOYSA-N ethane-1,2-diamine;oxalic acid Chemical compound NCCN.OC(=O)C(O)=O PQBMXAQBYJCLST-UHFFFAOYSA-N 0.000 description 4
- 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 description 3
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 3
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 description 3
- 239000003513 alkali Substances 0.000 description 3
- 229910001424 calcium ion Inorganic materials 0.000 description 3
- 239000012153 distilled water Substances 0.000 description 3
- 238000001914 filtration Methods 0.000 description 3
- 125000001165 hydrophobic group Chemical group 0.000 description 3
- 229910001425 magnesium ion Inorganic materials 0.000 description 3
- 230000007246 mechanism Effects 0.000 description 3
- NHLUVTZJQOJKCC-UHFFFAOYSA-N n,n-dimethylhexadecan-1-amine Chemical compound CCCCCCCCCCCCCCCCN(C)C NHLUVTZJQOJKCC-UHFFFAOYSA-N 0.000 description 3
- CHQMHPLRPQMAMX-UHFFFAOYSA-L sodium persulfate Substances [Na+].[Na+].[O-]S(=O)(=O)OOS([O-])(=O)=O CHQMHPLRPQMAMX-UHFFFAOYSA-L 0.000 description 3
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 2
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 2
- 230000002776 aggregation Effects 0.000 description 2
- 238000004220 aggregation Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 239000011575 calcium Substances 0.000 description 2
- 230000005465 channeling Effects 0.000 description 2
- 150000001875 compounds Chemical class 0.000 description 2
- 239000013078 crystal Substances 0.000 description 2
- 230000009881 electrostatic interaction Effects 0.000 description 2
- 238000011049 filling Methods 0.000 description 2
- 239000008398 formation water Substances 0.000 description 2
- 239000002736 nonionic surfactant Substances 0.000 description 2
- 238000001556 precipitation Methods 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- RTBFRGCFXZNCOE-UHFFFAOYSA-N 1-methylsulfonylpiperidin-4-one Chemical compound CS(=O)(=O)N1CCC(=O)CC1 RTBFRGCFXZNCOE-UHFFFAOYSA-N 0.000 description 1
- BVKZGUZCCUSVTD-UHFFFAOYSA-M Bicarbonate Chemical compound OC([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-M 0.000 description 1
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 1
- VEXZGXHMUGYJMC-UHFFFAOYSA-M Chloride anion Chemical compound [Cl-] VEXZGXHMUGYJMC-UHFFFAOYSA-M 0.000 description 1
- NPYPAHLBTDXSSS-UHFFFAOYSA-N Potassium ion Chemical compound [K+] NPYPAHLBTDXSSS-UHFFFAOYSA-N 0.000 description 1
- GSEJCLTVZPLZKY-UHFFFAOYSA-N Triethanolamine Chemical compound OCCN(CCO)CCO GSEJCLTVZPLZKY-UHFFFAOYSA-N 0.000 description 1
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Chemical compound NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 description 1
- 230000006978 adaptation Effects 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 150000003863 ammonium salts Chemical group 0.000 description 1
- JFCQEDHGNNZCLN-UHFFFAOYSA-N anhydrous glutaric acid Natural products OC(=O)CCCC(O)=O JFCQEDHGNNZCLN-UHFFFAOYSA-N 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 229910000019 calcium carbonate Inorganic materials 0.000 description 1
- 239000004202 carbamide Substances 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000004945 emulsification Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 239000011261 inert gas Substances 0.000 description 1
- 230000009878 intermolecular interaction Effects 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 238000010147 laser engraving Methods 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 125000001421 myristyl 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])[H] 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
- 238000011056 performance test Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000006116 polymerization reaction Methods 0.000 description 1
- 229910001414 potassium ion Inorganic materials 0.000 description 1
- 230000001376 precipitating effect Effects 0.000 description 1
- 230000002265 prevention Effects 0.000 description 1
- 125000001436 propyl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])[H] 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 229910001415 sodium ion Inorganic materials 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 239000007858 starting material Substances 0.000 description 1
- 230000002195 synergetic effect Effects 0.000 description 1
- 229920006029 tetra-polymer Polymers 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
-
- 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
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
-
- 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
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
Landscapes
- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Emulsifying, Dispersing, Foam-Producing Or Wetting Agents (AREA)
Abstract
The invention provides a self-assembled gel foam oil displacement agent suitable for a high-temperature high-salt fracture-cavity oil reservoir and a preparation method thereof, and belongs to the technical field of oilfield chemistry. The oil displacement agent comprises: 0.2 to 0.5 percent of quaternary amphiphilic hydrophobic association copolymer, 0.2 to 0.3 percent of betaine Gemini surfactant, 0.1 to 0.35 percent of amine oxide surfactant, 0.1 to 0.2 percent of heat-resistant polybasic acid anhydride, 0.02 to 0.07 percent of counter ion compound, 0.04 to 0.14 percent of chelating agent and the balance of water, wherein the inorganic salt content in the water is 10 to 22 percent, and the raw materials are prepared into a foam oil displacement agent by using a foam generator. The foam stability after foaming is obviously improved, the oil-water interfacial tension is obviously reduced by improving the fluidity of oil-water two-phase flow, expanding the swept volume, improving the oil washing efficiency, increasing the stratum energy and improving the seepage capability of oil phase liquid, thereby obviously improving the crude oil recovery ratio of a high-temperature high-salt fracture-cavity type oil reservoir.
Description
Technical Field
The invention relates to the technical field of oilfield chemistry, in particular to a self-assembled gel foam oil displacement agent suitable for a high-temperature high-salt fracture-cavity oil reservoir and a preparation method thereof.
Background
The fracture-cavity type oil reservoir has large resource potential, only the three-level reserves of the petroleum in the basin of the Tarim reach more than 30 hundred million tons, the oil reservoir is buried deeply (5000-7000 m), the temperature is up to 160 ℃, the mineralization degree is more than 20 ten thousand mg/L, the reservoir space mainly comprises large holes, large cracks and corrosion holes, the scale difference is large, the scale is from micron level to meter level, the heterogeneity is strong, the recovery ratio is generally low, the average recovery ratio in 2017 is only about 16.1 percent, and the recovery ratio is less than half of that of the clastic rock oil reservoir of the Tarim. The main method for improving the recovery ratio of the fracture-cavity oil deposit at present is water injection, gas injection and matched synergy technology, because 60% -70% of the fracture-cavity oil deposit is high in collapse and filling degree, the difference of flow characteristics of a fracture development area is large, the water flooding efficiency is low due to the fact that injection medium is easy to enter along a high-diversion channel, and the higher gas channeling risk exists in nitrogen injection flooding, a more effective recovery ratio improving method and theoretical guidance are needed to be searched, and the recovery ratio of the fracture-cavity oil deposit is further improved.
Based on the adjustment of a nitrogen flooding channel, the purpose of optimizing profile control is realized by optimizing a nitrogen injection matching medium, nitrogen foam is mainly used as a main adjusting medium, the foam has the characteristics of selective plugging, large plugging, small plugging and water plugging, and no oil plugging, the characteristics enable the foam flooding technology to have a huge development prospect in oil field development, and the crude oil recovery ratio is further improved by improving the oil-water interfacial tension, plugging and injecting the mechanisms such as dominant nitrogen migration high channel and the like. The nitrogen is used as inert gas, is not easy to react with stratum fluid and rock, is safe and economical, has low dissolving capacity in water, and reduces adverse effects caused by emulsification and precipitation blockage. Therefore, the test of nitrogen foam flooding can further enrich and develop the carbonate reservoir recovery rate improvement theory, and has important theoretical significance and practical significance. The nitrogen foam oil displacement technology is a tertiary oil recovery technology based on nitrogen displacement and with diversified oil displacement mechanisms, and shows great advantages in the oil and gas field exploitation process by means of the unique properties and the oil displacement mechanisms, and is widely focused at home and abroad.
Aiming at the problems of gas flooding effect and dominant wave of the fracture-cavity oil reservoir, a polymer foam flooding mine pilot test is carried out on TK647 wells of the Tahe oil field, a preliminary effect is obtained, and the feasibility of foam flooding is verified. From 2018, a total of 6-well polymer foam auxiliary gas-driven mining field tests are carried out on the Tahe oil field, wherein 3-well huff and puff are carried out on a single well, 4-well unit profile control and flooding are carried out, the oil change rate of square liquid is 2.14, and the accumulated oil increment is 5600 tons. The TK722CH2 well group polymer foam flooding test proves that the gas channeling prevention rate of the polymer foam system can reach 60%.
However, the temperature resistance and the salt resistance of the current foam oil displacement agent need to be improved.
Disclosure of Invention
In order to solve at least one of the problems, the invention provides a self-assembled gel foam oil displacement agent suitable for a high-temperature high-salt fracture-cavity oil reservoir, which can resist higher temperature, pressure and mineralization degree and can be applied to development of ultra-deep wells.
In order to achieve the above object, the technical scheme of the present invention is as follows: the self-assembled gel foam oil displacement agent suitable for the high-temperature high-salt fracture-cavity oil reservoir comprises the following components in percentage by weight: 0.2 to 0.5 percent of quaternary amphiphilic hydrophobic association copolymer, 0.2 to 0.3 percent of betaine Gemini surfactant, 0.1 to 0.35 percent of amine oxide surfactant, 0.1 to 0.2 percent of heat-resistant polybasic acid anhydride, 0.02 to 0.07 percent of counter ion compound, 0.04 to 0.14 percent of chelating agent and the balance of water, wherein the inorganic salt content in the water is 10 to 22 percent, and the raw materials are prepared into a foam oil displacement agent by using a foam generator;
the quaternary amphiphilic hydrophobic association copolymer is prepared from acryloylmorpholine, 3-allyloxy-1-hydroxy-1-propane sodium sulfonate, sodium p-styrenesulfonate and dicetyl methallyl ammonium chloride in a mass ratio of 4-6:0.25-0.5:0.25-0.5:0.1-0.3 through micelle copolymerization under the action of an initiator;
the structural formula of the betaine Gemini surfactant is as follows:
wherein R is C 12 H 25 。
Specifically, for the quaternary amphiphilic hydrophobic association copolymer, hydrophobic groups are mutually associated, so that the space network structure of polymer molecules in the solution is enhanced, the viscosity of the whole system is increased, meanwhile, the positive charge of quaternary ammonium salt cations and the negative charge ionized by polybasic acid anhydride can generate strong electrostatic interaction, the electrostatic interaction draws in the relative distance between the hydrophobic groups on different molecular chains, the hydrophobic association between the molecular chains is enhanced, the polymer can form a space network structure more easily in the solution, and the tackifying effect of the polymer is improved.
The dicetyl methallyl ammonium chloride (DiC, 16 DMAAC) monomer units in the quaternary amphiphilic hydrophobically associating copolymer can associate with each other to form an associating structure; the quaternary amphiphilic hydrophobic association copolymer, betaine type Gemini surfactant molecules and sodium salicylate react with each other to form a compound vermicular micelle structure; the heat-resistant polybasic acid anhydride and the quaternary amphiphilic hydrophobic association copolymer form an aggregation structure under the action of hydrogen bonds; the association structure, the composite worm-like micelle structure and the aggregation structure are mutually entangled to form a random coil with larger hydrodynamic volume, and an entangled structure is formed. The whole system is a dynamic and balanced network structure. And the concentration required for forming worm-like micelles with the same length finally is greatly reduced due to the hydrophobic association polymer of the tetrapolymer, so that the dosage of the surfactant is reduced.
For the vermiform micelle, the generation of calcium carbonate crystal nucleus and the growth of crystal can be effectively prevented, the composite vermiform micelle extruded by calcium and magnesium ions is effectively prevented from thinning an electric double layer and reducing the hydrodynamic volume of the micelle, so that the produced foam is fine and uniform, and the stability is good.
The synergistic effect of betaine type Gemini surfactant and amine oxide type nonionic surfactant leads to tighter arrangement of surfactant molecules on the oil-water interface, reduces the tension of the oil-water interface to be stronger, and can lead the tension value of the oil-water interface to reach an ultralow value.
In addition, long-chain hydrophobic groups exist in the betaine type Gemini surfactant, amine oxide surfactant and the dicetyl methyl allyl ammonium chloride (DiC 16 DMAAC) monomer units in the quaternary amphiphilic hydrophobically associating copolymer, so that the hydrophobically associating effect can be enhanced. The dicetyl methyl allyl ammonium chloride (DiC DMAAC) monomer units in the heat-resistant polybasic acid anhydride and quaternary amphiphilic hydrophobically associating copolymer are beneficial to improving the temperature resistance of foaming liquid. The betaine type Gemini surfactant, the amine oxide surfactant and the quaternary amphiphilic hydrophobic association copolymer can obviously improve the salt resistance of the foaming liquid.
One embodiment of the present invention is characterized in that the amine oxide surfactant is at least one of N, N-dimethyldodecylamine oxide, N-dimethyltetradecylamine oxide, and N, N-dimethylhexadecylamine oxide.
One embodiment of the present invention is that the heat-resistant polybasic acid anhydride is pyromellitic dianhydride.
One embodiment of the present invention is that the counter ion compound is sodium salicylate. Because the molecular weight of the counter ion is smaller, the self-assembled composite worm-like micelle is longer, and the viscosity is higher macroscopically.
One embodiment of the present invention is that the chelating agent is ethylenediamine tetraacetic acid and salts thereof.
In one embodiment of the present invention, the inorganic salt is at least one of sodium chloride, magnesium chloride, sodium sulfate, sodium bisulfate, sodium carbonate, potassium chloride, and calcium chloride.
The preparation method of the quaternary amphiphilic hydrophobically associating copolymer comprises the following specific preparation steps: adding acryloylmorpholine, 3-allyloxy-1-hydroxy-1-propane sodium sulfonate and sodium p-styrenesulfonate into water, dissolving, heating to 45-65 ℃, adding dicetyl methyl allyl ammonium chloride and an anionic surfactant, dissolving, introducing nitrogen to remove oxygen in the solution, adding a redox initiator, reacting for 3-6h at normal temperature, dripping the reaction liquid into a mixed solution of acetone and diethyl ether in a mass ratio of 1:1 to obtain a precipitate, and drying the precipitate to obtain the catalyst.
Further, the anionic surfactant is sodium dodecyl sulfate, and the mass ratio of the anionic surfactant to the sodium p-styrenesulfonate is 0.5-2: and 0.25-0.5, wherein the redox initiator is persulfate and bisulfite, and the addition amount of the redox initiator is similar to that of the conventional redox initiator and can be added according to actual conditions. In the present invention, in order to further enhance the polymerization effect, the redox initiator is defined as persulfate and bisulfite in a mass ratio of 1:1, and the mass ratio of acryloylmorpholine to the redox initiator is 4 to 6:0.4 to 0.8.
The invention further discloses a preparation method of the self-assembled gel foam oil displacement agent suitable for the high-temperature high-salt fracture-cavity oil reservoir, which comprises the following steps: adding quaternary amphiphilic hydrophobic association copolymer into water at 30-80 ℃, stirring to dissolve, sequentially adding betaine Gemini surfactant, amine oxide surfactant and chelating agent, stirring to dissolve, adding heat-resistant polybasic acid anhydride and counter ion compound, and stirring to dissolve; and then the obtained liquid is put on a foam generator to generate foam.
The beneficial effects are that: the four-component copolymerized hydrophobic association polymer, the betaine Gemini surfactant, the pyromellitic dianhydride and the sodium salicylate have four intermolecular interactions in the brine, so that a compound with a multi-layer structure can be formed, and the viscosity is higher. Under the same condition, the added amount is the same, and the viscosity formed by adopting a sodium salicylate system is far greater than that of a system formed by adopting sodium dodecyl sulfate; adopting pyromellitic acidThe viscosity of the anhydride-forming system is much greater than that of the system employing glutaric acid. Nitrogen is introduced, and after foaming, the produced foam is rich and fine and has longer half-life period; for the high-temperature high-salt fracture-cavity oil reservoir, when the nitrogen foam is injected, the nitrogen foam is resistant to salt and temperature, the foam system can not generate precipitation with calcium and magnesium ions, has good foamability and foam stability, and can enable the oil-water interfacial tension to reach 10 -3 On the order of mN/m.
The foam oil displacement agent disclosed by the invention does not contain alkali, so that the problems of reducing the viscoelasticity of a system, precipitating alkali and stratum water, increasing the difficulty in injection process and treatment of produced liquid, increasing cost and the like caused by the application of the alkali are avoided, meanwhile, the quaternary copolymer is added, the tackifying capability of foam liquid under high-temperature conditions is improved, the hydraulic radius of random coil formed after the foam liquid is dissolved in stratum water is large, the viscosity is high, the thickness of the foam liquid is high, and the karst cave and large cracks in a fracture-cave type oil reservoir can be effectively plugged;
the foam stability after foaming is obviously improved, the oil-water interfacial tension is obviously reduced by improving the fluidity of oil-water two-phase flow, expanding the swept volume, improving the oil washing efficiency, increasing the stratum energy and improving the seepage capability of oil phase liquid, thereby obviously improving the crude oil recovery ratio of a high-temperature high-salt fracture-cavity type oil reservoir.
Detailed Description
The following detailed description of the invention will be clearly and fully described in connection with the examples which are set forth to illustrate, but are not necessarily all embodiments of the invention.
The invention is further described below with reference to examples:
in the following examples, unless otherwise specified, the operations described are conventional in the art.
In the examples described below, the starting materials employed are all commercially available, unless otherwise specified.
In the following examples, the percentages are mass percentages unless otherwise indicated.
In the following examples, the structural formula of betaine Gemini surfactant is shown below:
wherein R is C 12 H 25 。
In the following examples, the foam flooding agent was prepared by the following method: under the condition of 85 ℃, adding quaternary amphiphilic hydrophobic association copolymer and betaine Gemini surfactant into water, stirring to dissolve, then adding amine oxide surfactant and chelating agent, stirring to dissolve, then adding counter ion compound and heat-resistant polybasic acid anhydride, and stirring to dissolve to obtain oil displacement agent solution. And then preparing the oil displacement agent solution into a foam oil displacement agent by using a high-temperature and high-pressure foaming device and nitrogen as an air source. In this embodiment, the foam generator shown in patent No. ZL201010130488.1 is used, but those skilled in the art may select other common high-temperature and high-pressure foam generators.
Wherein the inorganic salts in the water used in the different examples are shown in table 1.
TABLE 1 formation Water mineralization
| Examples | Sodium ions | Potassium ion | Calcium ion | Magnesium ions | Chloride ions | Bicarbonate ion | Total degree of mineralization |
| EXAMPLE 1 mg/L | 40452.5 | 13315 | 10665 | 8042.5 | 88242.5 | 3135.0 | 163852.5 |
| EXAMPLE 2 mg/L | 50161.1 | 16510.6 | 13224.6 | 9972.7 | 109420.7 | 3887.4 | 203177.1 |
| EXAMPLE 3 mg/L | 55015.4 | 17108.4 | 14165.0 | 10437.8 | 119009.8 | 4263.6 | 220000.0 |
Example 1
Preparation of quaternary amphiphilic hydrophobically associating copolymer: taking 10ml of distilled water, sequentially adding 6g of acryloylmorpholine, 0.25g of 3-allyloxy-1-hydroxy-1-propane sodium sulfonate and 0.25g of sodium p-styrenesulfonate, completely dissolving in water at normal temperature, then heating to 50 ℃, adding 0.2g of dicetyl methallyl ammonium chloride hydrophobic monomer and 1g of sodium dodecyl sulfate, and stirring until the monomers are completely dissolved; adding nitrogen to deoxidize for 10min, adding 0.2g of sodium persulfate and 0.2g of sodium bisulfate, reacting for 4h at normal temperature to obtain a uniform viscous solution, dripping the solution into 50ml of a mixed solution of anhydrous acetone and anhydrous diethyl ether with the mass ratio of 1:1, stirring to obtain a white precipitate, filtering, taking the precipitate, drying in vacuum at 50 ℃, and crushing to obtain the quaternary amphiphilic hydrophobic association copolymer.
Oil displacement agent solution components: the salt content of the quaternary amphiphilic hydrophobically associating copolymer, betaine Gemini surfactant, N-dimethyl hexadecyl amine oxide, pyromellitic dianhydride, sodium salicylate, ethylenediamine oxalic acid, and formation water in the balance of 0.5%, 0.2%, 0.1%, 0.03%, and the balance of the water are shown in Table 1.
Example 2
Preparation of quaternary amphiphilic hydrophobically associating copolymer: taking 10ml of distilled water, sequentially adding 5g of acryloylmorpholine, 0.4g of 3-allyloxy-1-hydroxy-1-propane sodium sulfonate and 0.4g of sodium p-styrenesulfonate, completely dissolving in water at normal temperature, then heating to 60 ℃, adding 0.3g of dicetyl methallyl ammonium chloride hydrophobic monomer and 2g of sodium dodecyl sulfate, and stirring until the monomers are completely dissolved; adding nitrogen to deoxidize for 10min, adding 0.3g of sodium persulfate and 0.3g of sodium bisulfate, reacting for 5h at normal temperature to obtain a uniform viscous solution, dripping the solution into 50ml of a mixed solution of anhydrous acetone and anhydrous diethyl ether with the mass ratio of 1:1, stirring to obtain a white precipitate, filtering, taking the precipitate, drying in vacuum at 50 ℃, and crushing to obtain the quaternary amphiphilic hydrophobic association copolymer.
Oil displacement agent solution components: 0.4% of quaternary amphiphilic hydrophobically associating copolymer, 0.25% of betaine Gemini surfactant, 0.3% of N, N-dimethyl hexadecyl amine oxide, 0.2% of pyromellitic dianhydride, 0.03% of sodium salicylate, 0.04% of ethylenediamine oxalic acid and the balance of water, wherein the salt content of the water is shown in table 1.
Example 3
Preparation of quaternary amphiphilic hydrophobically associating copolymer: taking 10ml of distilled water, sequentially adding 4g of acryloylmorpholine, 0.5g of 3-allyloxy-1-hydroxy-1-propane sodium sulfonate and 0.5g of sodium p-styrenesulfonate, completely dissolving in water at normal temperature, then heating to 55 ℃, adding 0.1g of dicetyl methallyl ammonium chloride hydrophobic monomer and 1.5g of sodium dodecyl sulfate, and stirring until the monomers are completely dissolved; adding nitrogen to deoxidize for 10min, adding 0.4g of sodium persulfate and 0.4g of sodium bisulfate, reacting for 6h at normal temperature to obtain a uniform viscous solution, dripping the solution into 50ml of a mixed solution of anhydrous acetone and anhydrous diethyl ether with the mass ratio of 1:1, stirring to obtain a white precipitate, filtering, taking the precipitate, drying in vacuum at 50 ℃, and crushing to obtain the quaternary amphiphilic hydrophobic association copolymer.
Oil displacement agent solution components: 0.3% of quaternary amphiphilic hydrophobically associating copolymer, 0.3% of betaine Gemini surfactant, 0.35% of N, N-dimethyl hexadecyl amine oxide, 0.15% of pyromellitic dianhydride, 0.03% of sodium salicylate, 0.10% of ethylenediamine oxalic acid and the balance of water, wherein the salt content of the water is shown in table 1.
To further illustrate the effects of the present invention, specific tests were performed on the oil-displacing agent of the above examples.
1. Viscosity, interfacial tension and foam properties
The viscosity of the oil-displacing agent solutions of examples 1 to 3 before foaming was measured by a high temperature and high pressure HAKEE rheometer at 150℃and 50MPa, and the oil-water interfacial tension was measured by a high temperature and high pressure Tax500 ultra-low rotation interfacial tensiometer. The final measurement results are shown in table 2.
The foam comprehensive index was tested using the Waring-Blender method, 200mL of the oil-displacing agent solution prepared in examples 1-3 was taken, wherein example 1 was heated to 40 ℃, wherein example 2 was heated to 60 ℃, wherein example 3 was heated to 80 ℃, and each was added to a stainless steel cup of an OWC-9360 constant speed stirrer, stirred for 1min at 4000r/min, poured into a measuring cylinder, and the initial foaming volume of the foam was immediately read and timed; when the foaming volume decreasesWhen the initial volume is half, the half-life period of the foam can be calculated by reading the time; the final results are shown in Table 2. From the initial volume and half-life of the foam, the foam composite index fci=0.75×v was calculated 0 *t 1/2 Wherein V is 0 For the foaming volume t 1/2 Is half-life.
Table 2 foam performance test
As can be seen from table 2, the present patent does not use triethanolamine and urea in comparison with the invention patent ZL 201710864250.3; compared with the embodiment corresponding to the invention patent ZL201710864250.3, the viscosity and the foam comprehensive index FCI of the foam oil displacement agent are obviously increased in the patent embodiments 1, 2 and 3.
For crude oil in oil field, the invention patent ZL201710864250.3 does not measure the oil-water interfacial tension, and we measure the interfacial tension of three embodiments, wherein the oil-water interfacial tension of the three embodiments is less than 10 -3 mN.m -1 The oil-water interfacial tension of the oil-displacing agent solutions of the present invention patent examples 1, 2 and 3 all reach 10 -3 mN.m -1 The magnitude order, therefore, the oil displacement agent of the invention reduces the interfacial tension of oil and water more strongly.
The total usage (0.66-1.36%) of the main agent (comprising quaternary amphiphilic hydrophobic association copolymer, bis { [ N-methyl-N- (3-dodecyloxy-2-hydroxy) propyl-N- (3-sodium sulfonate) propyl ] } ethylenebisquaternary ammonium salt, N-dimethyldodecane (or tetradecyl or hexadecyl) amine oxide, pyromellitic dianhydride, sodium salicylate and chelating agent ethylenediamine oxalate) used in the invention patent is far smaller than the total usage (0.66-1.36%) of the main agent (anionic surfactant, betaine type surfactant and nonionic surfactant) of the invention patent ZL201810856435.4, compared with 9 examples of the invention patent ZL201810856435.4, the half life of ZL201810856435.4 is seriously lost, and the experiment is repeated, so that the half life is only 3-5min, which is far lower than the data 17-22min in the table of the invention patent, therefore the invention patent foam has larger comprehensive index value, better self-assembling capability and better foam comprehensive property.
2. Oil displacement experiment
The oil displacement experiments were carried out by taking the oil displacement agents of examples 1 to 3, and the specific operations of the experiments are as follows: the self-assembled polymer gel foam oil displacement agent and the application are as follows: the self-assembled polymer gel foam oil displacement agent is injected into a full-size core (Lxd=300mm×100mm) for oil displacement experiments, the full-size core is vertically installed, the inlet is at the bottom, and the outlet is at the top. The full-size rock core is prepared by adopting carbonate outcrop of laser engraving of fracture and hole according to the fracture, hole and hole characteristics of fracture and hole type oil reservoir characteristics, and comprises the following specific operations: placing a full-size rock core of saturated hypersalinity stratum water into a vertical rock core holder at 150 ℃ and 50Mpa, adding confining pressure, checking the tightness of the system, and if the tightness is good, continuing the experiment; injecting crude oil into the rock core through the intermediate container until all the crude oil flows out of the outlet, and establishing original oil saturation; water-flooding crude oil to an economic limit (the water content is stabilized to 98%), establishing a water-flooding reservoir model, and calculating the water-flooding recovery ratio; and opening a valve, accessing the foam prepared by the sand filling pipe, adopting 0.5PV self-assembled polymer foam to displace crude oil, after the foam slug is completely injected, driving the subsequent water to the economic limit, and calculating the self-assembled polymer gel foam oil displacement agent to improve the recovery ratio of the crude oil. The core parameters of the cores used in examples 1-3 are shown in Table 3, and the displacement experiment results of the self-assembled polymer gel foam oil-displacing agent used in examples 1-3 are shown in Table 4.
The size of the core is 300mm 100mm, the fracture-cavity structure is prepared by carving carbonate outcrops through laser, the whole core is vertically installed, the bottom is an inlet, and the top is an outlet. The specific parameters are shown in Table 3.
Table 3 core parameters
Table 4 results of oil displacement test
| Core number | Water flooding efficiency/% | Steady flow differential pressure/mpa.m -1 | Poly/surface binary flooding enhanced recovery/% |
| Example 1 | 45.22 | 3.7 | 29.8 |
| Example 2 | 41.45 | 3.5 | 27.5 |
| Example 3 | 38.98 | 3.1 | 25.6 |
As can be seen from Table 4, even under the conditions of high temperature, high salt and high pressure, in the foam system prepared by the present invention, the recovery ratio is improved by 29.8%, 27.5% and 25.6% in the above 3 examples, respectively, and the lowest and highest oil displacement efficiencies of the oil displacement agents in the present invention are improved by 9.4% and 9.1% respectively, compared with the lowest and highest values of 16.2%, 20.5%, 18.9%, 17.3%, 18.1%, 18.5%, 19.1%, 20.7% and 18.8% in the 1-9 examples of the invention patent ZL201810856435.4, respectively, so that the oil displacement agent has higher oil displacement capacity.
In summary, the present invention is not limited to the preferred embodiments, but is intended to be limited to the specific embodiments described above, and any simple modification, equivalent changes and adaptations of the embodiments described above according to the technical principles of the present invention can be made by those skilled in the art without departing from the scope of the present invention.
Claims (9)
1. The self-assembled gel foam oil displacement agent suitable for the high-temperature high-salt fracture-cavity oil reservoir is characterized by comprising the following components in percentage by weight: 0.2 to 0.5 percent of quaternary amphiphilic hydrophobic association copolymer, 0.2 to 0.3 percent of betaine Gemini surfactant, 0.1 to 0.35 percent of amine oxide surfactant, 0.1 to 0.2 percent of heat-resistant polybasic acid anhydride, 0.02 to 0.07 percent of counter ion compound, 0.04 to 0.14 percent of chelating agent and the balance of water, wherein the inorganic salt content in the water is 10 to 22 percent, and the raw materials are prepared into a foam oil displacement agent by using a foam generator;
the quaternary amphiphilic hydrophobic association copolymer is prepared from acryloylmorpholine, 3-allyloxy-1-hydroxy-1-propane sodium sulfonate, sodium p-styrenesulfonate and dicetyl methallyl ammonium chloride in a mass ratio of 4-6:0.25-0.5:0.25-0.5:0.1-0.3 through micelle copolymerization under the action of an initiator;
the structural formula of the betaine Gemini surfactant is as follows:
wherein R is C 12 H 25 。
2. The self-assembled gel foam oil displacement agent suitable for high temperature and high salt fracture-cavity oil reservoirs according to claim 1, wherein the amine oxide surfactant is at least one of N, N-dimethyldodecylamine oxide, N-dimethyltetradecylamine oxide and N, N-dimethylhexadecylamine oxide.
3. The self-assembled gel foam oil displacement agent suitable for high-temperature high-salt fracture-cavity oil reservoirs according to claim 1, wherein the heat-resistant polybasic acid anhydride is pyromellitic dianhydride.
4. The self-assembled gel foam oil displacement agent suitable for high-temperature high-salt fracture-cavity oil reservoirs according to claim 1, wherein the counter ion compound is sodium salicylate.
5. The self-assembled gel foam oil displacement agent suitable for high-temperature high-salt fracture-cavity oil reservoirs according to claim 1, wherein the chelating agent is ethylenediamine tetraacetic acid and salts thereof.
6. The self-assembled gel foam oil displacement agent suitable for high-temperature high-salt fracture-cavity oil reservoirs, according to claim 1, wherein the inorganic salt is at least one of sodium chloride, magnesium chloride, sodium sulfate, sodium bisulfate, sodium carbonate, potassium chloride and calcium chloride.
7. The self-assembled gel foam oil displacement agent suitable for high-temperature high-salt fracture-cavity oil reservoirs, which is disclosed in claim 1, is characterized in that the specific preparation steps of the quaternary amphiphilic hydrophobically associating copolymer are as follows: adding acryloylmorpholine, 3-allyloxy-1-hydroxy-1-propane sodium sulfonate and sodium p-styrenesulfonate into water, dissolving, heating to 45-65 ℃, adding dicetyl methyl allyl ammonium chloride and an anionic surfactant, dissolving, introducing nitrogen to remove oxygen in the solution, adding a redox initiator, reacting for 3-6h at normal temperature, dripping the reaction liquid into a mixed solution of acetone and diethyl ether in a mass ratio of 1:1 to obtain a precipitate, and drying the precipitate to obtain the catalyst.
8. The self-assembled gel foam oil displacement agent suitable for high-temperature high-salt fracture-cavity oil reservoirs, according to claim 7, wherein the anionic surfactant is sodium dodecyl sulfate, and the mass ratio of the anionic surfactant to the sodium p-styrenesulfonate is 0.5-2:0.25-0.5, wherein the redox initiator is persulfate and bisulfite with the mass ratio of 1:1, and the mass ratio of the acryloylmorpholine to the redox initiator is 4-6:0.4-0.8.
9. The preparation method of the self-assembled gel foam oil displacement agent suitable for the high-temperature high-salt fracture-cavity oil reservoir as claimed in any one of claims 1 to 8, which is characterized by comprising the following steps: adding quaternary amphiphilic hydrophobic association copolymer into water at 30-80 ℃, stirring to dissolve, sequentially adding betaine Gemini surfactant, amine oxide surfactant and chelating agent, stirring to dissolve, adding heat-resistant polybasic acid anhydride and counter ion compound, and stirring to dissolve; and then the obtained liquid is put on a foam generator to generate foam.
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