WO2022252620A1 - Imbibition oil displacement agent and preparation method therefor - Google Patents
Imbibition oil displacement agent and preparation method therefor Download PDFInfo
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- WO2022252620A1 WO2022252620A1 PCT/CN2022/070745 CN2022070745W WO2022252620A1 WO 2022252620 A1 WO2022252620 A1 WO 2022252620A1 CN 2022070745 W CN2022070745 W CN 2022070745W WO 2022252620 A1 WO2022252620 A1 WO 2022252620A1
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- WIPO (PCT)
- Prior art keywords
- oil displacement
- displacement agent
- imbibition
- nano
- imbibition oil
- Prior art date
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- 238000006073 displacement reaction Methods 0.000 title claims abstract description 72
- 238000005213 imbibition Methods 0.000 title claims abstract description 68
- 238000002360 preparation method Methods 0.000 title claims abstract description 30
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 74
- 239000013543 active substance Substances 0.000 claims abstract description 43
- 239000000463 material Substances 0.000 claims abstract description 42
- 239000000178 monomer Substances 0.000 claims abstract description 32
- 239000002736 nonionic surfactant Substances 0.000 claims abstract description 20
- -1 acid anhydride compounds Chemical class 0.000 claims abstract description 19
- 230000002209 hydrophobic effect Effects 0.000 claims abstract description 17
- 239000002086 nanomaterial Substances 0.000 claims abstract description 15
- 230000035699 permeability Effects 0.000 claims abstract description 15
- 238000011161 development Methods 0.000 claims abstract description 14
- 239000002994 raw material Substances 0.000 claims abstract description 13
- 230000000379 polymerizing effect Effects 0.000 claims abstract description 4
- 239000003921 oil Substances 0.000 claims description 93
- 235000019198 oils Nutrition 0.000 claims description 89
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 44
- 238000003756 stirring Methods 0.000 claims description 28
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 20
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 18
- 239000002904 solvent Substances 0.000 claims description 18
- 150000002191 fatty alcohols Chemical class 0.000 claims description 12
- 235000019864 coconut oil Nutrition 0.000 claims description 11
- 239000003240 coconut oil Substances 0.000 claims description 11
- 235000014113 dietary fatty acids Nutrition 0.000 claims description 11
- 239000000194 fatty acid Substances 0.000 claims description 11
- 229930195729 fatty acid Natural products 0.000 claims description 11
- 150000004665 fatty acids Chemical class 0.000 claims description 11
- 239000003999 initiator Substances 0.000 claims description 11
- 238000006243 chemical reaction Methods 0.000 claims description 8
- GUJOJGAPFQRJSV-UHFFFAOYSA-N dialuminum;dioxosilane;oxygen(2-);hydrate Chemical compound O.[O-2].[O-2].[O-2].[Al+3].[Al+3].O=[Si]=O.O=[Si]=O.O=[Si]=O.O=[Si]=O GUJOJGAPFQRJSV-UHFFFAOYSA-N 0.000 claims description 6
- ONJQDTZCDSESIW-UHFFFAOYSA-N polidocanol Chemical compound CCCCCCCCCCCCOCCOCCOCCOCCOCCOCCOCCOCCOCCO ONJQDTZCDSESIW-UHFFFAOYSA-N 0.000 claims description 6
- 229910052901 montmorillonite Inorganic materials 0.000 claims description 5
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 4
- 230000003204 osmotic effect Effects 0.000 claims description 4
- 238000002156 mixing Methods 0.000 claims description 3
- USHAGKDGDHPEEY-UHFFFAOYSA-L potassium persulfate Chemical compound [K+].[K+].[O-]S(=O)(=O)OOS([O-])(=O)=O USHAGKDGDHPEEY-UHFFFAOYSA-L 0.000 claims description 3
- 125000004209 (C1-C8) alkyl group Chemical group 0.000 claims description 2
- 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 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 2
- 125000002947 alkylene group Chemical group 0.000 claims description 2
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 2
- 239000000440 bentonite Substances 0.000 claims description 2
- 229910000278 bentonite Inorganic materials 0.000 claims description 2
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 claims description 2
- 239000010439 graphite Substances 0.000 claims description 2
- 229910002804 graphite Inorganic materials 0.000 claims description 2
- 238000012986 modification Methods 0.000 claims description 2
- 230000004048 modification Effects 0.000 claims description 2
- CHQMHPLRPQMAMX-UHFFFAOYSA-L sodium persulfate Substances [Na+].[Na+].[O-]S(=O)(=O)OOS([O-])(=O)=O CHQMHPLRPQMAMX-UHFFFAOYSA-L 0.000 claims description 2
- 239000011149 active material Substances 0.000 claims 1
- 230000002195 synergetic effect Effects 0.000 abstract description 4
- 239000000243 solution Substances 0.000 description 35
- 239000000523 sample Substances 0.000 description 18
- 230000018109 developmental process Effects 0.000 description 12
- 238000012360 testing method Methods 0.000 description 12
- 239000011435 rock Substances 0.000 description 9
- 230000032683 aging Effects 0.000 description 7
- 230000000052 comparative effect Effects 0.000 description 7
- 239000010779 crude oil Substances 0.000 description 7
- 239000000203 mixture Substances 0.000 description 7
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 6
- 230000000694 effects Effects 0.000 description 5
- 239000007789 gas Substances 0.000 description 5
- 238000005325 percolation Methods 0.000 description 5
- 238000001179 sorption measurement Methods 0.000 description 5
- 239000004094 surface-active agent Substances 0.000 description 5
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 4
- 241000446313 Lamella Species 0.000 description 4
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 4
- 238000010438 heat treatment Methods 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 4
- 239000011159 matrix material Substances 0.000 description 4
- 238000000034 method Methods 0.000 description 4
- 239000001301 oxygen Substances 0.000 description 4
- 229910052760 oxygen Inorganic materials 0.000 description 4
- 238000011056 performance test Methods 0.000 description 4
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 3
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 3
- 239000008367 deionised water Substances 0.000 description 3
- 229910021641 deionized water Inorganic materials 0.000 description 3
- 239000003350 kerosene Substances 0.000 description 3
- 239000007788 liquid Substances 0.000 description 3
- FPYJFEHAWHCUMM-UHFFFAOYSA-N maleic anhydride Chemical class O=C1OC(=O)C=C1 FPYJFEHAWHCUMM-UHFFFAOYSA-N 0.000 description 3
- 229910052757 nitrogen Inorganic materials 0.000 description 3
- 239000011148 porous material Substances 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 description 2
- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical compound F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 description 2
- 239000006096 absorbing agent Substances 0.000 description 2
- 238000010521 absorption reaction Methods 0.000 description 2
- 150000001335 aliphatic alkanes Chemical class 0.000 description 2
- 235000019270 ammonium chloride Nutrition 0.000 description 2
- 239000010426 asphalt Substances 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 239000009096 changqing Substances 0.000 description 2
- 239000006185 dispersion Substances 0.000 description 2
- 238000004945 emulsification Methods 0.000 description 2
- 239000001257 hydrogen Substances 0.000 description 2
- 229910052739 hydrogen Inorganic materials 0.000 description 2
- 230000005660 hydrophilic surface Effects 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 238000000691 measurement method Methods 0.000 description 2
- 239000002120 nanofilm Substances 0.000 description 2
- 150000003839 salts Chemical class 0.000 description 2
- VZGDMQKNWNREIO-UHFFFAOYSA-N tetrachloromethane Chemical compound ClC(Cl)(Cl)Cl VZGDMQKNWNREIO-UHFFFAOYSA-N 0.000 description 2
- 238000009736 wetting Methods 0.000 description 2
- AXGOOCLYBPQWNG-UHFFFAOYSA-N 3-ethylfuran-2,5-dione Chemical compound CCC1=CC(=O)OC1=O AXGOOCLYBPQWNG-UHFFFAOYSA-N 0.000 description 1
- AYKYXWQEBUNJCN-UHFFFAOYSA-N 3-methylfuran-2,5-dione Chemical compound CC1=CC(=O)OC1=O AYKYXWQEBUNJCN-UHFFFAOYSA-N 0.000 description 1
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 1
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 1
- 241001465754 Metazoa Species 0.000 description 1
- ZLMJMSJWJFRBEC-UHFFFAOYSA-N Potassium Chemical compound [K] ZLMJMSJWJFRBEC-UHFFFAOYSA-N 0.000 description 1
- ZKLCLYSLODDVEW-UHFFFAOYSA-N [Cl-].[NH4+].C(CCCCCCCCCCCCCCCCC)C(=C(C)C)C Chemical compound [Cl-].[NH4+].C(CCCCCCCCCCCCCCCCC)C(=C(C)C)C ZKLCLYSLODDVEW-UHFFFAOYSA-N 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 125000000217 alkyl group Chemical group 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 125000004432 carbon atom Chemical group C* 0.000 description 1
- 235000012730 carminic acid Nutrition 0.000 description 1
- 230000005465 channeling Effects 0.000 description 1
- 238000013329 compounding Methods 0.000 description 1
- 239000012153 distilled water Substances 0.000 description 1
- 238000001035 drying Methods 0.000 description 1
- 238000004146 energy storage Methods 0.000 description 1
- 230000002431 foraging effect Effects 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 239000011521 glass Substances 0.000 description 1
- 238000009499 grossing Methods 0.000 description 1
- 230000036541 health Effects 0.000 description 1
- 125000004435 hydrogen atom Chemical group [H]* 0.000 description 1
- 230000015784 hyperosmotic salinity response Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 150000004968 peroxymonosulfuric acids Chemical class 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 239000011591 potassium Substances 0.000 description 1
- 229910052700 potassium Inorganic materials 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 239000012488 sample solution Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000011734 sodium Substances 0.000 description 1
- 229910052708 sodium Inorganic materials 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 238000009987 spinning Methods 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 238000009210 therapy by ultrasound Methods 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
- 238000004506 ultrasonic cleaning Methods 0.000 description 1
- 238000002525 ultrasonication Methods 0.000 description 1
- 238000005303 weighing Methods 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
- C09K8/584—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
Definitions
- the application relates to a imbibition oil displacement agent and a preparation method thereof, belonging to the technical field of oil and gas field development.
- low-permeability oil and gas reservoirs have the characteristics of poor reservoir physical properties, low formation energy, low permeability, slow conventional production, and difficult reservoir stimulation, which directly restrict the economic development of low-permeability oil and gas reservoirs.
- This part of the reservoir is often accompanied by naturally developed fractures or a rock matrix-fracture system is formed after reservoir reconstruction. The fractures play the role of conducting energy transfer, while the rock matrix plays the role of oil storage and energy storage.
- a kind of imbibition oil displacement agent is provided, the said imbibition oil displacement agent is added with nano-active agent material, combined with non-ionic surfactant, exerts the synergistic effect of both, and obtains an easy-to-prepare,
- the high-efficiency imbibition displacement agent (system) suitable for low-permeability reservoirs is of great significance and economic value to improve the development efficiency of low-permeability reservoirs.
- a kind of imbibition oil displacement agent, described imbibition oil displacement agent comprises following component:
- the nano-active agent material is obtained by polymerizing raw materials containing double bond-modified lamellar nano-materials, hydrophilic monomers and hydrophobic monomers;
- the hydrophilic monomer is selected from at least one of acid anhydride compounds
- the hydrophobic monomer is at least one selected from long-chain alkyl allyl quaternary ammonium salts.
- the percolation oil displacement agent includes the following components:
- the percolation oil displacement agent includes the following components:
- Non-ionic surfactant 30-40wt%
- the percolation oil displacement agent consists of the following components:
- the nonionic surfactant includes at least one of alkylphenol polyoxyethylene ether, fatty alcohol polyoxyethylene ether, and coconut oil fatty acid diethanolamide.
- the alkylphenol polyoxyethylene ether includes at least one of OP-9, OP-10, and TX-10;
- the fatty alcohol polyoxyethylene ether includes at least one of AEO-7 and AEO-9.
- the solvent III includes water.
- the percolation oil displacement agent includes the following components:
- the percolation oil displacement agent includes the following components:
- the double bond-modified lamella nanomaterial has at least one of the modifying groups shown in formula I;
- R 1 is selected from any one of C1-C4 alkylene
- R 2 is selected from any one of C1-C8 alkyl
- the sheet-layer nanomaterial is selected from at least one of montmorillonite, bentonite, and flake graphite.
- the montmorillonite is selected from sodium montmorillonite or calcium montmorillonite.
- the long-chain alkyl allyl quaternary ammonium salt is at least one selected from long-chain alkyl allyl ammonium halides.
- the long-chain alkyl allyl ammonium halide is selected from cetyl dimethyl propylene ammonium chloride, octadecyl dimethyl propylene ammonium chloride, tetradecyl dimethyl propylene ammonium chloride At least one of ammonium chloride, cetyl dimethyl allyl ammonium bromide.
- the acid anhydride compound is at least one selected from maleic anhydride compounds.
- the maleic anhydride compound is selected from at least one of maleic anhydride, methyl maleic anhydride, and ethyl maleic anhydride.
- the nano active agent material is obtained through the following steps:
- the mass ratio of the solution I to the solution II is 800-1200:15-25.
- the mass ratio of the solution I to the solution II is 900-1100:18-23.
- the mass ratio of the solution I to the solution II is 950-1050:20.
- the mass ratio of the double bond-modified lamella nanomaterial, the hydrophilic monomer and the hydrophobic monomer is 0.05-0.5:100-200:40-100.
- the mass ratio of the double bond-modified lamella nanomaterial, the hydrophilic monomer and the hydrophobic monomer is 0.05-0.3:140-180:50-90.
- the mass ratio of the double bond-modified lamella nanomaterial, the hydrophilic monomer and the hydrophobic monomer is 0.05-0.2:150-160:60-80.
- the initiator is selected from at least one of potassium persulfate, sodium persulfate, and ammonium persulfate.
- the solution I contains a solvent I;
- the solvent I is water.
- the mass ratio of the hydrophobic monomer to the solvent is 50-90:500-900.
- the mass ratio of the hydrophobic monomer to the solvent is 60-80:600-800.
- the solution I is obtained by the following steps: mixing the double-bonded modified sheet-layer nanomaterial, the hydrophilic monomer and the hydrophobic monomer, adding the solvent I, and removing oxygen to obtain The solution I.
- the solution II contains solvent II;
- the solvent II is water.
- the concentration of the initiator is 0.01-1 wt%.
- the upper limit of the concentration of the initiator is selected from 0.005%, 0.1%, 0.2%, 0.5%, 0.8% or 1%; the lower limit is selected from 0.001%, 0.005%, 0.1%, 0.2% %, 0.5% or 0.8%.
- the solution II is obtained through the following steps: dissolving the initiator in the solvent II and removing oxygen to obtain the solution II.
- the conditions of the reaction include: the temperature I is 50-80°C.
- the temperature I is 70-80°C.
- the conditions of the reaction include: the time is 2-5 hours.
- the time is 2.5-4.5 hours.
- the preparation method includes the following steps: heating the solution I to the temperature II under stirring, adding the solution II dropwise, raising the temperature to the temperature I, and reacting.
- the dropping speed is 2-7 g/min.
- the dropping speed is 3-5 g/min.
- the temperature II is 40-60°C.
- the stirring speed is 150-350 rpm.
- the heating rate is 2-8°C/min.
- the raw materials containing the nano-active agent material and the non-ionic surfactant are mixed to obtain the osmosis oil displacement agent.
- the preparation method comprises the following steps:
- the rotational speeds of the stirring I and the stirring II are independently 400-600 rpm.
- At least one of the imbibition oil displacement agent described in any one of the above, and at least one of the imbibition oil displacement agent prepared according to the preparation method described in any of the above is provided in low permeability and and/or applications in the development of fractured reservoirs.
- This application provides a low-permeability oil reservoir imbibition oil displacement agent and its preparation method and application.
- the imbibition oil displacement agent is mainly composed of nano-active agent materials, combined with surfactants, and exerts the synergistic effect of the two to form an easy
- the prepared high-efficiency imbibition oil displacement agent (system) suitable for low-permeability reservoirs has great significance and economic value for improving the development efficiency of low-permeability reservoirs.
- composition of described imbibition oil displacement agent comprises:
- nano active agent material (1) nano active agent material
- Nonionic surfactant one or more in alkylphenol polyoxyethylene ether, fatty alcohol polyoxyethylene ether, coconut oil fatty acid diethanolamide;
- the imbibition oil displacement agent includes: 20-60% of nano active agent material, 10-40% of non-ionic surface active agent, and the rest is water.
- C1-C4, C1-C8, etc. all refer to the number of carbon atoms contained in the group.
- alkyl refers to a group formed by losing any hydrogen atom on an alkane compound molecule.
- Alkane compounds include naphthenes, linear alkanes, and branched alkanes.
- OP-9, OP-10, and TX-10 are alkylphenol polyoxyethylene ethers
- AEO-7 and AEO-9 are fatty alcohol polyoxyethylene ethers.
- the added nano-active agent material forms a continuous adsorption layer on the oil-wet rock surface through electrostatic force, hydrogen bond and other chemical bonds, forming a hydrophilic surface to enhance the wettability of the system Ability to absorb oil droplets.
- the addition of nano-active agents increases the interfacial activity, forming a tighter and more stable adsorption arrangement at the oil-water interface, forming a strongly hydrophilic nano-film on the rock matrix wall, further improving the hydrophilicity of the rock, and further reducing the oil-water interface.
- Tension, better emulsification and dispersion of crude oil Under the comprehensive effect of changing the wetting performance and reducing the interfacial tension performance, the imbibition efficiency is finally greatly improved.
- the MT230 used in this application is sodium-based montmorillonite modified by double bonds, produced by Inner Mongolia Aimu Animal Health Products Co., Ltd., and the model is MT230;
- the nano-active agent material is obtained by the following steps:
- composition of raw materials 30wt% nano-active agent material, 20wt% fatty alcohol polyoxyethylene ether (specifically AEO-9), 20wt% coconut oil fatty acid diethanolamide, and the rest is water.
- Preparation method add fatty alcohol polyoxyethylene ether and coconut oil fatty acid diethanolamide into water, stir until uniform at a stirring speed of 400r/min, then add nano active agent material, and stir uniformly at the same speed to obtain the osmotic Oil-absorbing agent.
- composition of raw materials 60wt% nano-active agent material, 10wt% fatty alcohol polyoxyethylene ether (specifically AEO-9), 10wt% coconut oil fatty acid diethanolamide, and the rest is water.
- Preparation method add fatty alcohol polyoxyethylene ether and coconut oil fatty acid diethanolamide into water, stir until uniform at a stirring speed of 400r/min, then add nano-active agent material, and stir uniformly at the same speed to obtain the osmotic Oil-absorbing agent.
- Composition of raw materials 30wt% of nano active agent material, 20wt% of alkylphenol polyoxyethylene ether (specifically OP-10), 10wt% of coconut oil fatty acid diethanolamide, and the rest is water.
- Preparation method add alkylphenol polyoxyethylene ether and coconut oil fatty acid diethanolamide into water, stir until uniform at a stirring speed of 400r/min, then add nano-active agent material, and stir uniformly at the same speed to obtain the described Osmosis oil displacement agent.
- Composition of raw materials 60wt% of nano active agent material, the rest is water.
- Preparation method add the nano-active agent material into water, stir at a stirring speed of 500 r/min until uniform, and prepare the imbibition oil displacement agent.
- Raw material composition 30wt% fatty alcohol polyoxyethylene ether (specifically AEO-9), 30wt% coconut oil fatty acid diethanolamide, and the rest is water.
- Preparation method Add fatty alcohol polyoxyethylene ether and coconut oil fatty acid diethanolamide into water, stir at a stirring speed of 400r/min until uniform, and prepare the imbibition oil displacement agent.
- Chang 6 block simulated water (Chang 6 block simulated water: salinity 47470mg/L, the specific ion composition is shown in Table 1 below) to prepare sample solutions for the following performance tests.
- Test sample Dilute the low-permeability reservoir imbibition oil displacement agent in Examples 1-3 and Comparative Examples 1-2 with Chang 6 block simulated water by 200 times to obtain the sample to be tested;
- Test sample dilute the low-permeability oil reservoir imbibition oil displacement agent in Examples 1-3 and Comparative Examples 1-2 with the simulated water of Chang 6 block by 200 times to obtain the sample to be tested;
- the imbibition oil displacement agents for low-permeability reservoirs in Examples 1-3 and Comparative Examples 1-2 were diluted 200 times with simulated water from Chang 6 block to obtain samples to be tested. 1 Take the sample to be tested and add carmine indicator (addition amount is 0.01wt%), keep the solution temperature at 25 ⁇ 0.2°C, pour the solution to be tested into the cuvette to the top boundary, and stick the scale to the rear wall and stand behind it ;
- Test sample dilute the low-permeability oil reservoir imbibition flooding agent in Examples 1-3 and Comparative Examples 1-2 with the simulated water of Chang 6 block by 200 times to obtain the sample to be tested;
- For low-permeability sandstone core slices after smoothing the cut surface with sandpaper, clean the sandstone core slices with alcohol and distilled water, and place them in an oven for one day to dry;
- Test sample Dilute the low-permeability oil reservoir imbibition flooding agents in Examples 1-3 and Comparative Examples 1-2 by 200 times with Chang 6 block simulated water to obtain the sample to be tested;
- core preparation the experimental The cores were drilled, cut and dried to measure the gas permeability and porosity; all experimental cores were vacuumed and saturated with simulated formation water, and the constant pressure and constant speed pump was used to displace more than 5PV to measure the water phase permeability; followed by oil flooding, Flood the experimental core to the state of irreducible water, record the volume of displaced water, and measure the permeability of the oil phase under the irreducible water;
- Self-priming oil displacement efficiency/% (self-priming oil displacement volume/volume of water displaced by oil flooding) ⁇ 100%.
- Test sample dilute the low-permeability reservoir imbibition oil displacement agent in Examples 1-3 by 200 times with the simulated water of Chang 6 block to obtain the sample to be tested;
- Temperature resistance Dilute the low-permeability reservoir imbibition oil displacement agent in Examples 1-3 by 200 times with the simulated water of Chang 6 block to obtain the sample to be tested; seal the sample to be tested and place it in an oven at 150°C After aging for 3 days, after taking it out, test the performance after high-temperature aging according to the measurement methods of surface/interfacial tension, capillary self-absorption height, and contact angle.
- Salt tolerance Dilute the low-permeability reservoir imbibition flooding agent in Examples 1-3 by 200 times with 100000 mg/L salinity simulated brine to obtain the sample to be tested. According to the measurement methods of surface/interfacial tension, capillary self-priming height, and contact angle, the performance under this salinity is tested.
- the performance of the system after compounding the nano-active agent material and the surfactant is significantly enhanced compared with the individual nano-active agent material and surfactant, and the interfacial tension is an order of magnitude lower than that of the surfactant system.
- the imbibition efficiency is increased by more than 15%.
- the nano-active agent material forms a continuous adsorption layer on the surface of oil-wet rock through electrostatic force, hydrogen bond and other chemical bonds, and forms a hydrophilic surface to enhance the wettability change ability of the system and absorb oil droplets.
- the addition of nano-active agent materials increases the interfacial activity, forms a tighter and more stable adsorption arrangement at the oil-water interface, forms a strongly hydrophilic nano-film on the rock matrix wall, further improves the hydrophilicity of the rock, and further reduces oil-water Interfacial tension, better emulsification and dispersion of crude oil.
- Test 5 the performance test results of Examples 1, 2, and 3 after high-temperature aging are similar to those before aging, indicating that the samples have good temperature resistance and have no effect on performance.
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- Oil, Petroleum & Natural Gas (AREA)
- Life Sciences & Earth Sciences (AREA)
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- Materials Engineering (AREA)
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- Medicinal Preparation (AREA)
Abstract
The present application discloses an imbibition oil displacement agent and a preparation method therefor. The imbibition oil displacement agent comprises the following components: 20-60 parts by weight of a nano-active agent material, and 10-40 parts by weight of a nonionic surfactant. The nano-active agent material is obtained by polymerizing raw materials that contain a double bond modified lamellar nano-material, a hydrophilic monomer and a hydrophobic monomer; the hydrophilic monomer is selected from at least one among acid anhydride compounds; and the hydrophobic monomer is selected from at least one among long-chain alkyl allyl quaternary ammonium salts. The imbibition oil displacement agent is prepared by adding a nano-active agent material in combination with a nonionic surfactant to obtain a synergistic effect of the two so as to obtain a high-efficiency imbibition oil displacement agent (system) that is easy to prepare and is suitable for low-permeability oil reservoirs; in addition, the present invention has great significance and economic value for improving the development efficiency of low permeability reservoirs.
Description
本申请涉及一种渗吸驱油剂及其制备方法，属于油气田开发技术领域。The application relates to a imbibition oil displacement agent and a preparation method thereof, belonging to the technical field of oil and gas field development.
随着油气田开发的不断深入，许多油田进入了开发的中后期阶段，低渗透油藏成为老油田增产的重要领域，是今后进一步开采的主要对象。但低渗透油气藏由于储层物性差、地层能量低、渗透率低，常规投产见效慢，油藏改造难度大等特征，直接制约了低渗透油气藏的经济开发。这部分储层常常伴有自然发育裂缝或通过储层改造后形成岩块基质-裂缝系统，裂缝起到导流传能作用，而岩块基质起到储油储能作用。由于裂缝渗透率与基质岩块渗透率的显著差异，因此比常规油藏的开发难度更大，在常规水驱作业中常常存在水动力联系差，水窜水淹后大量剩余油富集，导致“注不进、采不出”等难题，给低渗透油藏的开发带来了巨大挑战。With the deepening of oil and gas field development, many oil fields have entered the middle and late stages of development, and low-permeability reservoirs have become an important area for increasing production in old oil fields and the main target for further exploitation in the future. However, low-permeability oil and gas reservoirs have the characteristics of poor reservoir physical properties, low formation energy, low permeability, slow conventional production, and difficult reservoir stimulation, which directly restrict the economic development of low-permeability oil and gas reservoirs. This part of the reservoir is often accompanied by naturally developed fractures or a rock matrix-fracture system is formed after reservoir reconstruction. The fractures play the role of conducting energy transfer, while the rock matrix plays the role of oil storage and energy storage. Due to the significant difference between fracture permeability and matrix block permeability, it is more difficult to develop than conventional reservoirs. In conventional water flooding operations, there is often poor hydrodynamic connection, and a large amount of remaining oil is enriched after water channeling and flooding, resulting in Difficulties such as "no injection, no production" have brought great challenges to the development of low-permeability reservoirs.
大量室内研究及开发实践表明，对于低渗、裂缝性油藏，在毛细管力作用下原油可以从孔径较小的孔道逐渐向大孔道汇集，最终实现油水置换，提高单井产量和采收率，因此充分发挥毛细管力的渗吸作用可成为这类油藏有效的开发方式，研发一种高效的渗吸驱油剂意义重大。现有渗吸驱油剂大多存在以下问题：(1)制备工艺复杂、不易操作、反应条件相对苛刻；(2)耐温耐盐性差，对地层吸附损耗大；(3)部分性能欠佳，导致渗吸效率不理想。A large number of laboratory studies and development practices have shown that for low-permeability and fractured reservoirs, under the action of capillary force, crude oil can gradually collect from pores with smaller pore diameters to large pores, and finally realize oil-water replacement, improving single well production and recovery. Therefore, the imbibition that fully exerts the capillary force can become an effective development method for this type of reservoir, and the development of an efficient imbibition displacement agent is of great significance. Most of the existing imbibition oil displacement agents have the following problems: (1) The preparation process is complicated, difficult to operate, and the reaction conditions are relatively harsh; (2) The temperature resistance and salt resistance are poor, and the adsorption loss to the formation is large; (3) Some properties are not good, Lead to unsatisfactory imbibition efficiency.
发明内容Contents of the invention
根据本申请的一个方面，提一种供渗吸驱油剂，所述渗吸驱油剂加入纳米活性剂材料，结合非离子表面活性剂，发挥两者协同作用，得到一种容易制备的、适用于低渗油藏的高效渗吸驱油剂(体系)， 对提高低渗油藏开发效率具有重要意义和经济价值。According to one aspect of the present application, a kind of imbibition oil displacement agent is provided, the said imbibition oil displacement agent is added with nano-active agent material, combined with non-ionic surfactant, exerts the synergistic effect of both, and obtains an easy-to-prepare, The high-efficiency imbibition displacement agent (system) suitable for low-permeability reservoirs is of great significance and economic value to improve the development efficiency of low-permeability reservoirs.
一种渗吸驱油剂，所述渗吸驱油剂包括以下组分：A kind of imbibition oil displacement agent, described imbibition oil displacement agent comprises following component:
纳米活性剂材料 20～60重量份；Nano active agent material 20-60 parts by weight;
非离子表面活性剂 10～40重量份；10-40 parts by weight of nonionic surfactant;
所述纳米活性剂材料通过将含有双键改性的片层纳米材料、亲水单体和疏水单体的原料聚合得到；The nano-active agent material is obtained by polymerizing raw materials containing double bond-modified lamellar nano-materials, hydrophilic monomers and hydrophobic monomers;
所述亲水单体选自酸酐类化合物中的至少一种；The hydrophilic monomer is selected from at least one of acid anhydride compounds;
所述疏水单体选自长链烷基烯丙基季铵盐中的至少一种。The hydrophobic monomer is at least one selected from long-chain alkyl allyl quaternary ammonium salts.
可选地，所述渗吸驱油剂包括以下组分：Optionally, the percolation oil displacement agent includes the following components:
纳米活性剂材料 20～60wt％；Nano active agent material 20～60wt%;
非离子表面活性剂 10～40wt％；Nonionic surfactant 10～40wt%;
溶剂III 余量；Solvent III balance;
可选地，所述渗吸驱油剂包括以下组分：Optionally, the percolation oil displacement agent includes the following components:
纳米活性剂材料 30～60wt％；Nano active agent material 30～60wt%;
非离子表面活性剂 30～40wt％；Non-ionic surfactant 30-40wt%;
溶剂III 余量。Solvent III balance.
可选地，所述渗吸驱油剂由以下组分组成：Optionally, the percolation oil displacement agent consists of the following components:
纳米活性剂材料 20～60wt％；Nano active agent material 20～60wt%;
非离子表面活性剂 10～40wt％；Nonionic surfactant 10～40wt%;
溶剂III 余量。Solvent III balance.
可选地，所述非离子表面活性剂包括烷基酚聚氧乙烯醚、脂肪醇聚氧乙烯醚、椰子油脂肪酸二乙醇酰胺中至少一种。Optionally, the nonionic surfactant includes at least one of alkylphenol polyoxyethylene ether, fatty alcohol polyoxyethylene ether, and coconut oil fatty acid diethanolamide.
可选地，所述烷基酚聚氧乙烯醚包括OP-9、OP-10、TX-10中的至少一种；Optionally, the alkylphenol polyoxyethylene ether includes at least one of OP-9, OP-10, and TX-10;
所述脂肪醇聚氧乙烯醚包括AEO-7、AEO-9中的至少一种。The fatty alcohol polyoxyethylene ether includes at least one of AEO-7 and AEO-9.
可选地，所述溶剂III包括水。Optionally, the solvent III includes water.
可选地，所述渗吸驱油剂包括以下组分：Optionally, the percolation oil displacement agent includes the following components:
可选地，所述渗吸驱油剂包括以下组分：Optionally, the percolation oil displacement agent includes the following components:
可选地，所述双键改性的片层纳米材料具有如式I所示的修饰基团中的至少一种；Optionally, the double bond-modified lamella nanomaterial has at least one of the modifying groups shown in formula I;
其中，R
1选自C1～C4亚烷基中的任一种，R
2选自C1～C8烷基中的任一种。
Wherein, R 1 is selected from any one of C1-C4 alkylene, and R 2 is selected from any one of C1-C8 alkyl.
可选地，所述片层纳米材料选自蒙脱土、膨润土、鳞片石墨中的至少一种。Optionally, the sheet-layer nanomaterial is selected from at least one of montmorillonite, bentonite, and flake graphite.
可选地，所述蒙脱土选自钠基蒙脱土或钙基蒙脱土。Optionally, the montmorillonite is selected from sodium montmorillonite or calcium montmorillonite.
可选地，所述长链烷基烯丙基季铵盐选自长链烷基烯丙基卤化铵中的至少一种。Optionally, the long-chain alkyl allyl quaternary ammonium salt is at least one selected from long-chain alkyl allyl ammonium halides.
可选地，所述长链烷基烯丙基卤化铵选自十六烷基二甲基丙烯氯化铵、十八烷基二甲基丙烯氯化铵、十四烷基二甲基丙烯氯化铵、十六烷基二甲基丙烯溴化铵中的至少一种。Optionally, the long-chain alkyl allyl ammonium halide is selected from cetyl dimethyl propylene ammonium chloride, octadecyl dimethyl propylene ammonium chloride, tetradecyl dimethyl propylene ammonium chloride At least one of ammonium chloride, cetyl dimethyl allyl ammonium bromide.
可选地，所述酸酐类化合物选自马来酸酐类化合物中的至少一种。Optionally, the acid anhydride compound is at least one selected from maleic anhydride compounds.
可选地，所述马来酸酐类化合物选自马来酸酐、甲基马来酸酐、乙基马来酸酐中的至少一种。Optionally, the maleic anhydride compound is selected from at least one of maleic anhydride, methyl maleic anhydride, and ethyl maleic anhydride.
可选地，所述纳米活性剂材料通过以下步骤得到：Optionally, the nano active agent material is obtained through the following steps:
将含有所述双键改性的片层纳米材料、所述亲水单体和所述疏水单体的溶液I和含有引发剂的溶液II混合、反应，得到所述纳米活性剂材料。Mixing and reacting the solution I containing the double bond-modified sheet-layer nanomaterial, the hydrophilic monomer and the hydrophobic monomer, and the solution II containing an initiator to obtain the nano active agent material.
可选地，所述溶液I和所述溶液II的质量比为800～1200：15～25。Optionally, the mass ratio of the solution I to the solution II is 800-1200:15-25.
可选地，所述溶液I和所述溶液II的质量比为900～1100：18～23。Optionally, the mass ratio of the solution I to the solution II is 900-1100:18-23.
可选地，所述溶液I和所述溶液II的质量比为950～1050：20。Optionally, the mass ratio of the solution I to the solution II is 950-1050:20.
可选地，所述溶液I中，所述双键改性的片层纳米材料、所述亲水单体和所述疏水单体的质量比为0.05～0.5：100～200：40～100。Optionally, in the solution I, the mass ratio of the double bond-modified lamella nanomaterial, the hydrophilic monomer and the hydrophobic monomer is 0.05-0.5:100-200:40-100.
可选地，所述双键改性的片层纳米材料、所述亲水单体和所述疏水单体的质量比为0.05～0.3：140～180：50～90。Optionally, the mass ratio of the double bond-modified lamella nanomaterial, the hydrophilic monomer and the hydrophobic monomer is 0.05-0.3:140-180:50-90.
可选地，所述双键改性的片层纳米材料、所述亲水单体和所述疏水单体的质量比为0.05～0.2：150～160：60～80。Optionally, the mass ratio of the double bond-modified lamella nanomaterial, the hydrophilic monomer and the hydrophobic monomer is 0.05-0.2:150-160:60-80.
可选地，所述引发剂选自过硫酸钾、过硫酸钠、过硫酸铵中的至少一种。Optionally, the initiator is selected from at least one of potassium persulfate, sodium persulfate, and ammonium persulfate.
可选地，所述溶液I含有溶剂I；Optionally, the solution I contains a solvent I;
所述溶剂I为水。The solvent I is water.
可选地，所述溶液I中，所述疏水单体与所述溶剂的质量比为50～90：500～900。Optionally, in the solution I, the mass ratio of the hydrophobic monomer to the solvent is 50-90:500-900.
可选地，所述溶液I中，所述疏水单体与所述溶剂的质量比为60～80：600～800。Optionally, in the solution I, the mass ratio of the hydrophobic monomer to the solvent is 60-80:600-800.
可选地，所述溶液I通过以下步骤得到：将所述双键的改性片层纳米材料、所述亲水单体和所述疏水单体混合，加入所述溶剂I，除氧，得到所述溶液I。Optionally, the solution I is obtained by the following steps: mixing the double-bonded modified sheet-layer nanomaterial, the hydrophilic monomer and the hydrophobic monomer, adding the solvent I, and removing oxygen to obtain The solution I.
可选地，所述溶液II含有溶剂II；Optionally, the solution II contains solvent II;
所述溶剂II为水。The solvent II is water.
可选地，所述溶液II中，所述引发剂的浓度为0.01～1wt％。Optionally, in the solution II, the concentration of the initiator is 0.01-1 wt%.
可选地，所述溶液II中，所述引发剂的浓度上限选自0.005％、0.1％、0.2％、0.5％、0.8％或1％；下限选自0.001％、0.005％、0.1％、0.2％、0.5％或0.8％。Optionally, in the solution II, the upper limit of the concentration of the initiator is selected from 0.005%, 0.1%, 0.2%, 0.5%, 0.8% or 1%; the lower limit is selected from 0.001%, 0.005%, 0.1%, 0.2% %, 0.5% or 0.8%.
可选地，所述溶液II通过以下步骤得到：将所述引发剂溶解于所述溶剂II，除氧，得到所述溶液II。Optionally, the solution II is obtained through the following steps: dissolving the initiator in the solvent II and removing oxygen to obtain the solution II.
可选地，所述反应的条件包括：温度I为50～80℃。Optionally, the conditions of the reaction include: the temperature I is 50-80°C.
可选地，所述温度I为70～80℃。Optionally, the temperature I is 70-80°C.
可选地，所述反应的条件包括：时间为2～5h。Optionally, the conditions of the reaction include: the time is 2-5 hours.
可选地，所述时间为2.5～4.5h。Optionally, the time is 2.5-4.5 hours.
可选地，所述制备方法包括以下步骤：搅拌下，将所述溶液I升温至温度II，滴加所述溶液II，升温至温度I，反应。Optionally, the preparation method includes the following steps: heating the solution I to the temperature II under stirring, adding the solution II dropwise, raising the temperature to the temperature I, and reacting.
可选地，所述滴加的速度为2～7g/min。Optionally, the dropping speed is 2-7 g/min.
可选地，所述滴加的速度为3～5g/min。Optionally, the dropping speed is 3-5 g/min.
可选地，所述温度II为40～60℃。Optionally, the temperature II is 40-60°C.
可选地，所述搅拌的转速为150～350rpm。Optionally, the stirring speed is 150-350 rpm.
可选地，所述升温的速率为2～8℃/min。Optionally, the heating rate is 2-8°C/min.
根据本申请的另一个方面，提供上述任一项所述的渗吸驱油剂的制备方法，所述制备方法包括以下步骤：According to another aspect of the present application, there is provided a preparation method of any one of the above-mentioned imbibition oil displacement agents, the preparation method comprising the following steps:
将含有所述纳米活性剂材料、所述非离子表面活性剂的原料混合，得到所述渗吸驱油剂。The raw materials containing the nano-active agent material and the non-ionic surfactant are mixed to obtain the osmosis oil displacement agent.
可选地，所述制备方法包括以下步骤：Optionally, the preparation method comprises the following steps:
将所述非离子表面活性剂加入所述溶剂III中，搅拌I，得到溶液A，将所述纳米活性剂材料加入所述溶液A，搅拌II，得到所述渗吸驱油剂；adding the nonionic surfactant into the solvent III, stirring I to obtain solution A, adding the nano-active agent material to the solution A, stirring II, obtaining the osmotic oil displacement agent;
可选地，所述搅拌I和搅拌II的转速独立地为400～600rpm。Optionally, the rotational speeds of the stirring I and the stirring II are independently 400-600 rpm.
根据本申请的另一个方面，提供上述任一项所述的渗吸驱油剂、根据提供上述任一项所述的制备方法制备得到的渗吸驱油剂中的至少一种在低渗和/或裂缝性油藏开发中的应用。According to another aspect of the present application, at least one of the imbibition oil displacement agent described in any one of the above, and at least one of the imbibition oil displacement agent prepared according to the preparation method described in any of the above is provided in low permeability and and/or applications in the development of fractured reservoirs.
本申请提供一种低渗油藏渗吸驱油剂及其制备方法和应用，该渗吸驱油剂以纳米活性剂材料为主，结合表面活性剂，发挥两者协同作用，形成一种容易制备的、适用于低渗油藏的高效渗吸驱油剂(体系)，对提高低渗油藏开发效率具有重要意义和经济价值。This application provides a low-permeability oil reservoir imbibition oil displacement agent and its preparation method and application. The imbibition oil displacement agent is mainly composed of nano-active agent materials, combined with surfactants, and exerts the synergistic effect of the two to form an easy The prepared high-efficiency imbibition oil displacement agent (system) suitable for low-permeability reservoirs has great significance and economic value for improving the development efficiency of low-permeability reservoirs.
所述渗吸驱油剂的组成包括：The composition of described imbibition oil displacement agent comprises:
(1)纳米活性剂材料；(1) nano active agent material;
(2)非离子表面活性剂：烷基酚聚氧乙烯醚、脂肪醇聚氧乙烯 醚、椰子油脂肪酸二乙醇酰胺中的一种或多种；(2) Nonionic surfactant: one or more in alkylphenol polyoxyethylene ether, fatty alcohol polyoxyethylene ether, coconut oil fatty acid diethanolamide;
(3)水。(3) Water.
以质量百分比计，该渗吸驱油剂包括：20～60％纳米活性剂材料、10～40％非离子表面活性剂、其余为水。In terms of mass percentage, the imbibition oil displacement agent includes: 20-60% of nano active agent material, 10-40% of non-ionic surface active agent, and the rest is water.
所述渗吸驱油剂的制备方法：The preparation method of described imbibition oil displacement agent:
按配比称取各原料，在水中加入非离子表面活性剂，以400-600r/min的搅拌速度搅拌至均匀，再加入纳米活性剂材料，以同样的速度搅拌均匀，制得所属渗吸驱油剂。Weigh each raw material according to the ratio, add non-ionic surfactant in water, stir until uniform at a stirring speed of 400-600r/min, then add nano-active agent material, and stir uniformly at the same speed to obtain the corresponding imbibition flooding oil agent.
本申请中，本申请中，C1～C4、C1～C8等均指基团所包含的碳原子数。In the present application, in the present application, C1-C4, C1-C8, etc. all refer to the number of carbon atoms contained in the group.
本申请中，“烷基”是指由烷烃化合物分子上失去任意一个氢原子形成的基团。烷烃化合物包括环烷烃、直链烷烃、支链烷烃。In the present application, "alkyl" refers to a group formed by losing any hydrogen atom on an alkane compound molecule. Alkane compounds include naphthenes, linear alkanes, and branched alkanes.
本申请中，OP-9、OP-10、TX-10为烷基酚聚氧乙烯醚、AEO-7、AEO-9为脂肪醇聚氧乙烯醚。In this application, OP-9, OP-10, and TX-10 are alkylphenol polyoxyethylene ethers, and AEO-7 and AEO-9 are fatty alcohol polyoxyethylene ethers.
本申请能产生的有益效果包括：The beneficial effect that this application can produce comprises:
(1)本申请所提供的渗吸驱油，加入纳米活性剂材料，结合非离子表面活性剂，发挥两者协同作用，得到一种容易制备的、适用于低渗油藏的高效渗吸驱油剂(体系)，对提高低渗油藏开发效率具有重要意义和经济价值。(1) In the imbibition flooding provided by this application, nano-active agent materials are added, combined with non-ionic surfactants, and the synergistic effect of the two is exerted to obtain a high-efficiency imbibition flooding that is easy to prepare and is suitable for low-permeability reservoirs. Oil agent (system) is of great significance and economic value to improve the development efficiency of low permeability reservoirs.
(2)本申请所提供的渗吸驱油，所添加的纳米活性剂材料通过静电力、氢键等化学键作用在油湿岩石表面形成连续的吸附层，形成亲水表面增强体系润湿性改变能力，吸附油滴。同时纳米活性剂的加入增加了界面活性，在油水界面形成更为紧密和稳定的吸附排列，在岩石基质壁面上形成强亲水的纳米薄膜，进一步提高岩石的亲水性，同时进一步降低油水界面张力，更好的乳化分散原油。在改变润湿性能、降低界面张力性能的增强的综合作用下，最终使渗吸效率大幅提高。(2) In the imbibition flooding provided by this application, the added nano-active agent material forms a continuous adsorption layer on the oil-wet rock surface through electrostatic force, hydrogen bond and other chemical bonds, forming a hydrophilic surface to enhance the wettability of the system Ability to absorb oil droplets. At the same time, the addition of nano-active agents increases the interfacial activity, forming a tighter and more stable adsorption arrangement at the oil-water interface, forming a strongly hydrophilic nano-film on the rock matrix wall, further improving the hydrophilicity of the rock, and further reducing the oil-water interface. Tension, better emulsification and dispersion of crude oil. Under the comprehensive effect of changing the wetting performance and reducing the interfacial tension performance, the imbibition efficiency is finally greatly improved.
(3)本申请所提供的渗吸驱油耐温性良好。(3) The imbibition flooding provided by this application has good temperature resistance.
下面结合实施例详述本申请，但本申请并不局限于这些实施例。The present application is described in detail below in conjunction with the examples, but the present application is not limited to these examples.
如无特别说明，本申请的实施例中的原料均通过商业途径购买。Unless otherwise specified, the raw materials in the examples of the present application were purchased through commercial channels.
其中，本申请所用的MT230为经过双键改性的钠基蒙脱土，由内蒙古爱牧动物保健品有限公司生产，型号为MT230；纳米活性剂材料通过以下步骤得到：Wherein, the MT230 used in this application is sodium-based montmorillonite modified by double bonds, produced by Inner Mongolia Aimu Animal Health Products Co., Ltd., and the model is MT230; the nano-active agent material is obtained by the following steps:
(1)称取155.6g马来酸酐，68.38g十六烷基二甲基丙烯氯化铵(AO-4)以及0.1g MT230至三口烧瓶中，加入755g的去离子水，搅拌溶解，通氮气30min，排除溶液中的氧气；(1) Weigh 155.6g of maleic anhydride, 68.38g of hexadecyldimethylpropylene ammonium chloride (AO-4) and 0.1g of MT230 into a three-necked flask, add 755g of deionized water, stir to dissolve, and blow nitrogen 30min, remove the oxygen in the solution;
(2)称取1g的引发剂过硫酸钾，加20g去离子水，搅拌溶解(引发剂浓度0.5wt％)，通氮气15min，排除溶液中的氧气；(2) take by weighing the initiator potassium persulfate of 1g, add 20g deionized water, stir and dissolve (initiator concentration 0.5wt%), logical nitrogen 15min, get rid of the oxygen in the solution;
(3)250rpm机械搅拌(1)中得到的溶液，开始加热，设置加热温度55℃；等(1)中得到的溶液温度到达55℃时用恒压漏斗滴加(2)中得到的过硫酸钾溶液，同时将反应温度设置为80℃，7min滴完引发剂，等反应溶液温度到达80℃后开始计时，3h后结束反应，得到纳米活性剂材料，分子量为10万～30万，粒径10～100nm。(3) The solution obtained in (1) was mechanically stirred at 250rpm, started heating, and the heating temperature was set at 55°C; when the solution temperature obtained in (1) reached 55°C, add the persulfuric acid obtained in (2) dropwise with a constant pressure funnel Potassium solution, set the reaction temperature to 80°C at the same time, drop the initiator in 7 minutes, start timing when the temperature of the reaction solution reaches 80°C, and stop the reaction after 3 hours to obtain nano-active agent materials with a molecular weight of 100,000 to 300,000 and a particle size of 10-100nm.
长6区块原油为长庆油田方提供。The crude oil in Chang 6 Block is provided by Changqing Oilfield.
实施例1 低渗油藏渗吸驱油剂的制备Example 1 Preparation of imbibition oil displacement agent for low permeability reservoir
原料组成：30wt％纳米活性剂材料，20wt％脂肪醇聚氧乙烯醚(具体为AEO-9)，20wt％椰子油脂肪酸二乙醇酰胺，其余为水。Composition of raw materials: 30wt% nano-active agent material, 20wt% fatty alcohol polyoxyethylene ether (specifically AEO-9), 20wt% coconut oil fatty acid diethanolamide, and the rest is water.
制备方法：将脂肪醇聚氧乙烯醚和椰子油脂肪酸二乙醇酰胺加入水中，以400r/min的搅拌速度搅拌至均匀，再加入纳米活性剂材料，以同样的速度搅拌均匀，制得所述渗吸驱油剂。Preparation method: add fatty alcohol polyoxyethylene ether and coconut oil fatty acid diethanolamide into water, stir until uniform at a stirring speed of 400r/min, then add nano active agent material, and stir uniformly at the same speed to obtain the osmotic Oil-absorbing agent.
实施例2 低渗油藏渗吸驱油剂的制备Example 2 Preparation of imbibition oil displacement agent for low permeability reservoirs
原料组成：60wt％纳米活性剂材料，10wt％脂肪醇聚氧乙烯醚(具体为AEO-9)，10wt％椰子油脂肪酸二乙醇酰胺，其余为水。Composition of raw materials: 60wt% nano-active agent material, 10wt% fatty alcohol polyoxyethylene ether (specifically AEO-9), 10wt% coconut oil fatty acid diethanolamide, and the rest is water.
制备方法：将脂肪醇聚氧乙烯醚和椰子油脂肪酸二乙醇酰胺加入水中，以400r/min的搅拌速度搅拌至均匀，再加入纳米活性剂材料， 以同样的速度搅拌均匀，制得所述渗吸驱油剂。Preparation method: add fatty alcohol polyoxyethylene ether and coconut oil fatty acid diethanolamide into water, stir until uniform at a stirring speed of 400r/min, then add nano-active agent material, and stir uniformly at the same speed to obtain the osmotic Oil-absorbing agent.
实施例3 低渗油藏渗吸驱油剂的制备Example 3 Preparation of imbibition oil displacement agent for low permeability reservoirs
原料组成：：30wt％纳米活性剂材料，20wt％烷基酚聚氧乙烯醚(具体为OP-10)，10wt％椰子油脂肪酸二乙醇酰胺，其余为水。Composition of raw materials: 30wt% of nano active agent material, 20wt% of alkylphenol polyoxyethylene ether (specifically OP-10), 10wt% of coconut oil fatty acid diethanolamide, and the rest is water.
制备方法：将烷基酚聚氧乙烯醚和椰子油脂肪酸二乙醇酰胺加入水中，以400r/min的搅拌速度搅拌至均匀，再加入纳米活性剂材料，以同样的速度搅拌均匀，制得所述渗吸驱油剂。Preparation method: add alkylphenol polyoxyethylene ether and coconut oil fatty acid diethanolamide into water, stir until uniform at a stirring speed of 400r/min, then add nano-active agent material, and stir uniformly at the same speed to obtain the described Osmosis oil displacement agent.
对比例1 低渗油藏渗吸驱油剂的制备Comparative example 1 Preparation of imbibition oil displacement agent for low permeability reservoir
原料组成：60wt％纳米活性剂材料，其余为水。Composition of raw materials: 60wt% of nano active agent material, the rest is water.
制备方法：将纳米活性剂材料加入水中，以500r/min的搅拌速度搅拌至均匀，制得所述渗吸驱油剂。Preparation method: add the nano-active agent material into water, stir at a stirring speed of 500 r/min until uniform, and prepare the imbibition oil displacement agent.
对比例2 低渗油藏渗吸驱油剂的制备Comparative example 2 Preparation of imbibition oil displacement agent for low permeability reservoir
原料组成：30wt％脂肪醇聚氧乙烯醚(具体为AEO-9)，30wt％椰子油脂肪酸二乙醇酰胺，其余为水。Raw material composition: 30wt% fatty alcohol polyoxyethylene ether (specifically AEO-9), 30wt% coconut oil fatty acid diethanolamide, and the rest is water.
制备方法：将脂肪醇聚氧乙烯醚和椰子油脂肪酸二乙醇酰胺加入水中，以400r/min的搅拌速度搅拌至均匀，制得所述渗吸驱油剂。Preparation method: Add fatty alcohol polyoxyethylene ether and coconut oil fatty acid diethanolamide into water, stir at a stirring speed of 400r/min until uniform, and prepare the imbibition oil displacement agent.
性能测试方法：Performance test method:
使用配制的长6区块模拟水(长6区块模拟水：矿化度47470mg/L，具体离子组成如下表1所示)配制样品溶液进行下列性能测试。Use the prepared Chang 6 block simulated water (Chang 6 block simulated water: salinity 47470mg/L, the specific ion composition is shown in Table 1 below) to prepare sample solutions for the following performance tests.
表1 长6区块模拟水性质列表Table 1 List of simulated water properties in Chang 6 block
1.表/界面张力1. Surface/interfacial tension
表面张力：Surface Tension:
(1)测试样品：用长6区块模拟水将实施例1～3及对比例1～2中 的低渗油藏渗吸驱油剂稀释200倍，得到待测样品；(1) Test sample: Dilute the low-permeability reservoir imbibition oil displacement agent in Examples 1-3 and Comparative Examples 1-2 with Chang 6 block simulated water by 200 times to obtain the sample to be tested;
(2)测定步骤：在25℃条件下用表面张力仪进行测试，连续测量三次取平均值；(2) Measuring steps: test with a surface tensiometer at 25°C, and take the average value of three consecutive measurements;
界面张力：Interfacial tension:
(1)测试样品：用长6区块模拟水将实施例1～3及对比例1～2中的低渗油藏渗吸驱油剂稀释200倍，得到待测样品；(1) Test sample: dilute the low-permeability oil reservoir imbibition oil displacement agent in Examples 1-3 and Comparative Examples 1-2 with the simulated water of Chang 6 block by 200 times to obtain the sample to be tested;
(2)测定步骤：在60℃条件下用TX-500型旋转滴界面张力仪，以长6区块原油为油样，连续测量三次取平均值。(2) Determination procedure: use TX-500 spinning drop interfacial tensiometer under the condition of 60°C, take Chang 6 block crude oil as the oil sample, measure continuously for three times and take the average value.
2.毛管自吸高度2. Capillary self-priming height
(1)亲油毛细管的制备(1) Preparation of lipophilic capillary
①毛细管规格：标准毛细管内径0.35mm依次用四氯化碳、苯：丙酮：乙醇＝7:1.5:1.5(体积比)进行超声处理30min，除去表面有机物质；① Capillary specification: the standard capillary inner diameter is 0.35 mm, followed by carbon tetrachloride, benzene: acetone: ethanol = 7:1.5:1.5 (volume ratio) for ultrasonic treatment for 30 minutes to remove surface organic substances;
②再依次用稀盐酸溶液(1:10)，氢氟酸溶液(10％)进行超声，对毛细管表面进行粗糙、活化30min；用去离子水进行超声清洗，除去残留的酸，直至pH＞6.5，105℃烘干；②Use dilute hydrochloric acid solution (1:10) and hydrofluoric acid solution (10%) for ultrasonication in turn to roughen and activate the surface of the capillary for 30 minutes; use deionized water for ultrasonic cleaning to remove residual acid until pH > 6.5 , drying at 105°C;
③按照比例配置老化油，老化油组成为原油：航空煤油：90#沥青＝2:5:3；将处理后的毛细管完全浸没在老化油中，60℃温度条件下老化2～4周；③ Configure aging oil according to the ratio, and the aging oil is composed of crude oil: aviation kerosene: 90# asphalt = 2:5:3; completely immerse the treated capillary in the aging oil, and age at 60°C for 2 to 4 weeks;
④将毛细管取出，用煤油进行浸润2min清洗毛细管内外壁沉积的沥青，以不影响观察为准；用氮气将管外煤油吹干，放置在60℃密闭环境下烘干，得到油湿毛细管，保存备用。④ Take out the capillary, soak it with kerosene for 2 minutes to clean the asphalt deposited on the inner and outer walls of the capillary, as long as it does not affect the observation; dry the kerosene outside the tube with nitrogen, place it in a closed environment at 60°C and dry it to obtain an oil-wet capillary, and store it spare.
(2)测试制样(2) Test sample preparation
用长6区块模拟水将实施例1～3及对比例1～2中的低渗油藏渗吸驱油剂稀释200倍，得到待测样品。①取待测样品加入胭脂红指示剂(添加量为0.01wt％)，保持溶液温度为25±0.2℃，将待测溶液倒入比色皿中至顶端边界，将标尺紧贴后壁立于后方；The imbibition oil displacement agents for low-permeability reservoirs in Examples 1-3 and Comparative Examples 1-2 were diluted 200 times with simulated water from Chang 6 block to obtain samples to be tested. ① Take the sample to be tested and add carmine indicator (addition amount is 0.01wt%), keep the solution temperature at 25±0.2°C, pour the solution to be tested into the cuvette to the top boundary, and stick the scale to the rear wall and stand behind it ;
②将处理好的毛细管竖直放置于比色皿中，使用载玻片保持所有测试用毛细管倾斜角度一致(倾斜角度为垂直放置)，读取记录管中 液位高度与比色皿高度的高度差，分别记录毛细管没入液面10min时的液位高度。②Place the treated capillary vertically in the cuvette, use a glass slide to keep the inclination angle of all test capillaries consistent (the inclination angle is vertical), and read the height of the liquid level in the recording tube and the height of the cuvette Record the liquid level when the capillary is submerged in the liquid surface for 10 minutes.
3.接触角3. Contact angle
测试样品：用长6区块模拟水将实施例1～3及对比例1～2中的低渗油藏渗吸驱油剂稀释200倍，得到待测样品；(1)准备5mm左右厚度的低渗砂岩岩心切片，用砂纸将切面打磨平整后，用酒精和蒸馏水清洗砂岩岩心片，在烘箱中放置一天进行干燥；Test sample: dilute the low-permeability oil reservoir imbibition flooding agent in Examples 1-3 and Comparative Examples 1-2 with the simulated water of Chang 6 block by 200 times to obtain the sample to be tested; For low-permeability sandstone core slices, after smoothing the cut surface with sandpaper, clean the sandstone core slices with alcohol and distilled water, and place them in an oven for one day to dry;
(2)将岩心片放入长庆原油中，60℃浸泡48h以上进行老化，使其成为油湿表面；(2) Put the core piece into Changqing crude oil, soak it at 60°C for more than 48 hours for aging, so that it becomes an oil-wet surface;
(3)取出砂岩岩心片，用纸将表面油擦拭干净，然后浸泡在待测样品中，置于60℃的烘箱中24h，使用克吕士DSA25型接触角测量仪测量岩心片表面、空气、水三相接触角，连续测量三次取平均值。(3) Take out the sandstone core piece, wipe off the surface oil with paper, then soak it in the sample to be tested, put it in an oven at 60°C for 24 hours, and measure the surface, air, Water three-phase contact angle, the average value of three consecutive measurements.
4.渗吸效率4. Imbibition efficiency
测试样品：用长6区块模拟水将实施例1～3及对比例1～2中的低渗油藏渗吸驱油剂稀释200倍，得到待测样品；(1)岩心准备：将实验岩心钻切并烘干，测定气测渗透率和孔隙度；所有实验岩心抽真空用模拟地层水饱和，用恒压恒速泵驱替5PV以上，测定水相渗透率；接着进行油驱水，将实验岩心驱替至束缚水状态，记录驱出水体积，并测定束缚水下油相渗透率；Test sample: Dilute the low-permeability oil reservoir imbibition flooding agents in Examples 1-3 and Comparative Examples 1-2 by 200 times with Chang 6 block simulated water to obtain the sample to be tested; (1) core preparation: the experimental The cores were drilled, cut and dried to measure the gas permeability and porosity; all experimental cores were vacuumed and saturated with simulated formation water, and the constant pressure and constant speed pump was used to displace more than 5PV to measure the water phase permeability; followed by oil flooding, Flood the experimental core to the state of irreducible water, record the volume of displaced water, and measure the permeability of the oil phase under the irreducible water;
(2)将实验岩心放入装有待测样品的自吸仪，让岩心自吸排油，记录随时间变化的排油量；当排出油的体积连续72h不再变化，记录总的排油体积，进行自吸效率计算。(2) Put the experimental rock core into the self-absorption instrument equipped with the sample to be tested, let the core self-absorb and discharge oil, and record the oil discharge volume changing with time; when the volume of the discharged oil does not change for 72 hours, record the total oil discharge volume , to calculate the self-priming efficiency.
(3)自吸驱油效率/％＝(自吸排油体积/油驱水驱出水体积)×100％。(3) Self-priming oil displacement efficiency/%=(self-priming oil displacement volume/volume of water displaced by oil flooding)×100%.
5.耐温耐盐性5. Temperature and salt resistance
测试样品：用长6区块模拟水将实施例1～3中的低渗油藏渗吸驱油剂稀释200倍，得到待测样品；Test sample: dilute the low-permeability reservoir imbibition oil displacement agent in Examples 1-3 by 200 times with the simulated water of Chang 6 block to obtain the sample to be tested;
耐温性：用长6区块模拟水将实施例1～3中的低渗油藏渗吸驱油 剂稀释200倍，得到待测样品；将待测样品样品密封后置于150℃烘箱中老化3天，取出后分别按照表/界面张力、毛管自吸高度、接触角的测量方法测试高温老化后的性能。Temperature resistance: Dilute the low-permeability reservoir imbibition oil displacement agent in Examples 1-3 by 200 times with the simulated water of Chang 6 block to obtain the sample to be tested; seal the sample to be tested and place it in an oven at 150°C After aging for 3 days, after taking it out, test the performance after high-temperature aging according to the measurement methods of surface/interfacial tension, capillary self-absorption height, and contact angle.
耐盐性：用100000mg/L矿化度模拟盐水将实施例1～3中的低渗油藏渗吸驱油剂稀释200倍，得到待测样品。分别按照表/界面张力、毛管自吸高度、接触角的测量方法测试该矿化度下的性能。Salt tolerance: Dilute the low-permeability reservoir imbibition flooding agent in Examples 1-3 by 200 times with 100000 mg/L salinity simulated brine to obtain the sample to be tested. According to the measurement methods of surface/interfacial tension, capillary self-priming height, and contact angle, the performance under this salinity is tested.
性能测试结果：Performance test results:
测试1～4的结果如表2所示。The results of tests 1-4 are shown in Table 2.
表2 测试1～4的结果Table 2 Results of tests 1 to 4
由表2中的实验结果可以看出，纳米活性剂材料与表面活性剂复配后的体系性能较单独纳米活性剂材料及表面活性剂明显增强，其中界面张力较表面活性剂体系降低一个数量级，渗吸效率提高15％以上。As can be seen from the experimental results in Table 2, the performance of the system after compounding the nano-active agent material and the surfactant is significantly enhanced compared with the individual nano-active agent material and surfactant, and the interfacial tension is an order of magnitude lower than that of the surfactant system. The imbibition efficiency is increased by more than 15%.
纳米活性剂材料通过静电力、氢键等化学键作用在油湿岩石表面形成连续的吸附层，形成亲水表面增强体系润湿性改变能力，吸附油滴。同时纳米活性剂材料的加入增加了界面活性，在油水界面形成更为紧密和稳定的吸附排列，在岩石基质壁面上形成强亲水的纳米薄膜，进一步提高岩石的亲水性，同时进一步降低油水界面张力，更好的乳化分散原油。The nano-active agent material forms a continuous adsorption layer on the surface of oil-wet rock through electrostatic force, hydrogen bond and other chemical bonds, and forms a hydrophilic surface to enhance the wettability change ability of the system and absorb oil droplets. At the same time, the addition of nano-active agent materials increases the interfacial activity, forms a tighter and more stable adsorption arrangement at the oil-water interface, forms a strongly hydrophilic nano-film on the rock matrix wall, further improves the hydrophilicity of the rock, and further reduces oil-water Interfacial tension, better emulsification and dispersion of crude oil.
在改变润湿性能、降低界面张力性能的增强的综合作用下，最终使渗吸效率大幅提高。Under the comprehensive effect of changing the wetting performance and reducing the interfacial tension performance, the imbibition efficiency is finally greatly improved.
测试5中，实施例1、2、3经高温老化后各性能测试结果与老化前相近，说明样品耐温性良好，对性能无影响。In Test 5, the performance test results of Examples 1, 2, and 3 after high-temperature aging are similar to those before aging, indicating that the samples have good temperature resistance and have no effect on performance.
以上所述，仅是本申请的几个实施例，并非对本申请做任何形式的限制，虽然本申请以较佳实施例揭示如上，然而并非用以限制本申请，任何熟悉本专业的技术人员，在不脱离本申请技术方案的范围内，利用上述揭示的技术内容做出些许的变动或修饰均等同于等效实施案例，均属于技术方案范围内。The above are only a few embodiments of the application, and do not limit the application in any form. Although the application is disclosed as above with preferred embodiments, it is not intended to limit the application. Any skilled person familiar with this field, Without departing from the scope of the technical solution of the present application, any changes or modifications made using the technical content disclosed above are equivalent to equivalent implementation cases, and all belong to the scope of the technical solution.
Claims (21)
- 一种渗吸驱油剂，其特征在于，所述渗吸驱油剂包括以下组分：A kind of imbibition oil displacement agent, is characterized in that, described imbibition oil displacement agent comprises following component:纳米活性剂材料 20～60重量份；Nano active agent material 20-60 parts by weight;非离子表面活性剂 10～40重量份；10-40 parts by weight of nonionic surfactant;所述纳米活性剂材料通过将含有双键改性的片层纳米材料、亲水单体和疏水单体的原料聚合得到；The nano-active agent material is obtained by polymerizing raw materials containing double bond-modified lamellar nano-materials, hydrophilic monomers and hydrophobic monomers;所述亲水单体选自酸酐类化合物中的至少一种；The hydrophilic monomer is selected from at least one of acid anhydride compounds;所述疏水单体选自长链烷基烯丙基季铵盐中的至少一种。The hydrophobic monomer is at least one selected from long-chain alkyl allyl quaternary ammonium salts.
- 一种渗吸驱油剂，其特征在于，所述渗吸驱油剂包括以下组分：A kind of imbibition oil displacement agent, is characterized in that, described imbibition oil displacement agent comprises following component:纳米活性剂材料 20～60wt％；Nano active agent material 20～60wt%;非离子表面活性剂 10～40wt％；Nonionic surfactant 10～40wt%;溶剂III 余量；Solvent III balance;所述纳米活性剂材料通过将含有双键改性的片层纳米材料、亲水单体和疏水单体的原料聚合得到；The nano-active agent material is obtained by polymerizing raw materials containing double bond-modified lamellar nano-materials, hydrophilic monomers and hydrophobic monomers;所述亲水单体选自酸酐类化合物中的至少一种；The hydrophilic monomer is selected from at least one of acid anhydride compounds;所述疏水单体选自长链烷基烯丙基季铵盐中的至少一种。The hydrophobic monomer is at least one selected from long-chain alkyl allyl quaternary ammonium salts.
- 根据权利要求2所述的渗吸驱油剂，其特征在于，所述渗吸驱油剂包括以下组分：The oil displacement agent according to claim 2, wherein the oil displacement agent comprises the following components:纳米活性剂材料 30～60wt％；Nano active agent material 30～60wt%;非离子表面活性剂 30～40wt％；Non-ionic surfactant 30-40wt%;溶剂III 余量。Solvent III balance.
- 根据权利要求1所述的渗吸驱油剂，其特征在于，所述渗吸驱油剂由以下组分组成：The imbibition oil displacement agent according to claim 1, wherein the imbibition oil displacement agent is composed of the following components:纳米活性剂材料 20～60wt％；Nano active agent material 20～60wt%;非离子表面活性剂 10～40wt％；Nonionic surfactant 10～40wt%;溶剂III 余量。Solvent III balance.
- 根据权利要求1或2所述的渗吸驱油剂，其特征在于，所述非离子表面活性剂包括烷基酚聚氧乙烯醚、脂肪醇聚氧乙烯醚、椰子油脂肪酸二乙醇酰胺中至少一种。The imbibition oil displacement agent according to claim 1 or 2, is characterized in that, described nonionic surfactant comprises at least in alkylphenol polyoxyethylene ether, fatty alcohol polyoxyethylene ether, coconut oil fatty acid diethanolamide A sort of.
- 根据权利要求5所述的渗吸驱油剂，其特征在于，所述烷基酚聚氧乙烯醚包括OP-9、OP-10、TX-10中的至少一种；The imbibition oil displacement agent according to claim 5, wherein the alkylphenol polyoxyethylene ether comprises at least one of OP-9, OP-10, and TX-10;所述脂肪醇聚氧乙烯醚包括AEO-7、AEO-9中的至少一种。The fatty alcohol polyoxyethylene ether includes at least one of AEO-7 and AEO-9.
- 根据权利要求2～4任一项所述的渗吸驱油剂，其特征在于，所述溶剂III包括水。The imbibition oil displacement agent according to any one of claims 2-4, characterized in that the solvent III includes water.
- 根据权利要求5所述的渗吸驱油剂，其特征在于，所述渗吸驱油剂包括以下组分：The oil displacement agent according to claim 5, characterized in that, the oil displacement agent comprises the following components:
- 根据权利要求5所述的渗吸驱油剂，其特征在于，所述渗吸驱油剂包括以下组分：The oil displacement agent according to claim 5, characterized in that, the oil displacement agent comprises the following components:
- 根据权利要求1或2所述的渗吸驱油剂，其特征在于，所述双键改性的片层纳米材料具有如式I所示的修饰基团中的至少一种；The imbibition oil displacement agent according to claim 1 or 2, wherein the sheet-layer nanomaterial modified by the double bond has at least one of the modification groups shown in formula I;
其中，R 1选自C1～C4亚烷基中的任一种，R 2选自C1～C8烷基中的任一种。 Wherein, R 1 is selected from any one of C1-C4 alkylene, and R 2 is selected from any one of C1-C8 alkyl. - 根据权利要求1或2所述的渗吸驱油剂，其特征在于，所述片层纳米材料选自蒙脱土、膨润土、鳞片石墨中的至少一种。The imbibition oil displacement agent according to claim 1 or 2, characterized in that, the sheet-layer nanomaterial is selected from at least one of montmorillonite, bentonite, and flake graphite.
- 根据权利要求1或2所述的渗吸驱油剂，其特征在于，所述纳米活性剂材料通过以下步骤得到：The imbibition oil displacement agent according to claim 1 or 2, wherein the nano-active agent material is obtained through the following steps:将含有所述双键改性的片层纳米材料、所述亲水单体和所述疏水单体的溶液I和含有引发剂的溶液II混合、反应，得到所述纳米活性剂材料。Mixing and reacting the solution I containing the double bond-modified sheet-layer nanomaterial, the hydrophilic monomer and the hydrophobic monomer, and the solution II containing an initiator to obtain the nano active agent material.
- 根据权利要求12所述的渗吸驱油剂，其特征在于，所述溶液I中，所述双键改性的片层纳米材料、所述亲水单体和所述疏水单体的质量比为0.05～0.5：100～200：40～100。The imbibition oil displacement agent according to claim 12, characterized in that, in the solution I, the mass ratio of the double bond modified sheet nanomaterial, the hydrophilic monomer and the hydrophobic monomer 0.05-0.5: 100-200: 40-100.
- 根据权利要求12所述的渗吸驱油剂，其特征在于，所述引发剂选自过硫酸钾、过硫酸钠、过硫酸铵中的至少一种。The imbibition oil displacement agent according to claim 12, characterized in that the initiator is selected from at least one of potassium persulfate, sodium persulfate and ammonium persulfate.
- 根据权利要求12所述的渗吸驱油剂，其特征在于，所述溶液II中，所述引发剂的浓度为0.01～1wt％。The imbibition oil displacement agent according to claim 12, characterized in that, in the solution II, the concentration of the initiator is 0.01-1 wt%.
- 根据权利要求12所述的渗吸驱油剂，其特征在于，所述反应的条件包括：温度I为50～80℃。The imbibition oil displacement agent according to claim 12, characterized in that the reaction conditions include: the temperature I is 50-80°C.
- 根据权利要求12所述的渗吸驱油剂，其特征在于，所述反应的条件包括：时间为2～5h。The imbibition oil displacement agent according to claim 12, characterized in that the reaction conditions include: the time is 2-5 hours.
- 权利要求1～17任一项所述渗吸驱油剂的制备方法，其特征在于，所述制备方法包括以下步骤：The preparation method of the imbibition oil displacement agent described in any one of claims 1 to 17, characterized in that the preparation method comprises the following steps:将含有所述纳米活性剂材料、所述非离子表面活性剂的原料混合，得到所述渗吸驱油剂。The raw materials containing the nano-active agent material and the non-ionic surfactant are mixed to obtain the osmosis oil displacement agent.
- 根据权利要求18所述的制备方法，其特征在于，所述制备方法包括以下步骤：The preparation method according to claim 18, characterized in that, the preparation method comprises the following steps:将所述非离子表面活性剂加入所述溶剂III中，搅拌I，得到溶液A，将所述纳米活性剂材料加入所述溶液A，搅拌II，得到所述渗吸驱油剂。Add the non-ionic surfactant into the solvent III, stir I to obtain solution A, add the nano-active material to the solution A, stir II, obtain the osmotic oil displacement agent.
- 根据权利要求18所述的制备方法，其特征在于，所述搅拌I和搅拌II的转速独立地为400～600rpm。The preparation method according to claim 18, characterized in that, the rotational speeds of the stirring I and the stirring II are independently 400-600 rpm.
- 权利要求1～17任一项所述的渗吸驱油剂、根据权利要求18～20任一项所述的制备方法制备得到的渗吸驱油剂中的至少一种在低渗和/或裂缝性油藏开发中的应用。At least one of the imbibition oil displacement agent described in any one of claims 1 to 17 and the imbibition oil displacement agent prepared according to the preparation method described in any one of claims 18 to 20 is in low permeability and/or Applications in the development of fractured reservoirs.
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