CN110317598A - Improve compact reservoir CO2Drive the aqueous solution of effect and its preparation method and application method - Google Patents
Improve compact reservoir CO2Drive the aqueous solution of effect and its preparation method and application method Download PDFInfo
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- CN110317598A CN110317598A CN201810291614.8A CN201810291614A CN110317598A CN 110317598 A CN110317598 A CN 110317598A CN 201810291614 A CN201810291614 A CN 201810291614A CN 110317598 A CN110317598 A CN 110317598A
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- aqueous solution
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- 239000007864 aqueous solution Substances 0.000 title claims abstract description 64
- 230000000694 effects Effects 0.000 title claims abstract description 49
- 238000000034 method Methods 0.000 title claims abstract description 28
- 238000002360 preparation method Methods 0.000 title claims abstract description 17
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 72
- 239000003921 oil Substances 0.000 claims abstract description 62
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 60
- 230000004048 modification Effects 0.000 claims abstract description 32
- 238000012986 modification Methods 0.000 claims abstract description 32
- 239000004094 surface-active agent Substances 0.000 claims abstract description 31
- 230000000740 bleeding effect Effects 0.000 claims abstract description 25
- 238000002347 injection Methods 0.000 claims abstract description 13
- 239000007924 injection Substances 0.000 claims abstract description 13
- 235000019198 oils Nutrition 0.000 claims description 56
- -1 olefin sulfonate Chemical class 0.000 claims description 21
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 13
- 229910019142 PO4 Inorganic materials 0.000 claims description 12
- KWIUHFFTVRNATP-UHFFFAOYSA-N glycine betaine Chemical compound C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 claims description 12
- 239000010452 phosphate Substances 0.000 claims description 12
- QXNVGIXVLWOKEQ-UHFFFAOYSA-N Disodium Chemical compound [Na][Na] QXNVGIXVLWOKEQ-UHFFFAOYSA-N 0.000 claims description 9
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 9
- NBIIXXVUZAFLBC-UHFFFAOYSA-K phosphate Chemical compound [O-]P([O-])([O-])=O NBIIXXVUZAFLBC-UHFFFAOYSA-K 0.000 claims description 9
- MJJJJEUEZVGFLW-UHFFFAOYSA-N 2-dodecyl-2-sulfobutanedioic acid Chemical compound CCCCCCCCCCCCC(S(O)(=O)=O)(C(O)=O)CC(O)=O MJJJJEUEZVGFLW-UHFFFAOYSA-N 0.000 claims description 8
- ILRSCQWREDREME-UHFFFAOYSA-N dodecanamide Chemical compound CCCCCCCCCCCC(N)=O ILRSCQWREDREME-UHFFFAOYSA-N 0.000 claims description 8
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 7
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 7
- PMZURENOXWZQFD-UHFFFAOYSA-L Sodium Sulfate Chemical group [Na+].[Na+].[O-]S([O-])(=O)=O PMZURENOXWZQFD-UHFFFAOYSA-L 0.000 claims description 4
- 150000002191 fatty alcohols Chemical class 0.000 claims description 4
- QLNJFJADRCOGBJ-UHFFFAOYSA-N propionamide Chemical compound CCC(N)=O QLNJFJADRCOGBJ-UHFFFAOYSA-N 0.000 claims description 4
- 229910052708 sodium Inorganic materials 0.000 claims description 4
- 239000011734 sodium Substances 0.000 claims description 4
- 229910052938 sodium sulfate Inorganic materials 0.000 claims description 4
- 235000011152 sodium sulphate Nutrition 0.000 claims description 4
- 150000001408 amides Chemical class 0.000 claims description 3
- 235000019864 coconut oil Nutrition 0.000 claims description 3
- 239000003240 coconut oil Substances 0.000 claims description 3
- 239000004519 grease Substances 0.000 claims description 3
- JRZJOMJEPLMPRA-UHFFFAOYSA-N olefin Natural products CCCCCCCC=C JRZJOMJEPLMPRA-UHFFFAOYSA-N 0.000 claims description 3
- 230000009467 reduction Effects 0.000 claims description 3
- 239000002352 surface water Substances 0.000 claims description 3
- 239000008399 tap water Substances 0.000 claims description 3
- 235000020679 tap water Nutrition 0.000 claims description 3
- KBPLFHHGFOOTCA-UHFFFAOYSA-N 1-Octanol Chemical compound CCCCCCCCO KBPLFHHGFOOTCA-UHFFFAOYSA-N 0.000 claims 2
- 238000011084 recovery Methods 0.000 abstract description 21
- 238000006073 displacement reaction Methods 0.000 abstract description 14
- 239000010779 crude oil Substances 0.000 abstract description 10
- 239000011159 matrix material Substances 0.000 abstract description 10
- 239000000243 solution Substances 0.000 abstract description 7
- 230000008859 change Effects 0.000 abstract description 2
- 238000005213 imbibition Methods 0.000 abstract description 2
- 229910002092 carbon dioxide Inorganic materials 0.000 description 50
- 239000006260 foam Substances 0.000 description 13
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 12
- 239000004088 foaming agent Substances 0.000 description 11
- 230000008569 process Effects 0.000 description 9
- 235000019441 ethanol Nutrition 0.000 description 8
- 239000000203 mixture Substances 0.000 description 8
- 239000002585 base Substances 0.000 description 6
- 239000013043 chemical agent Substances 0.000 description 6
- JJDGTGGQXAAVQX-UHFFFAOYSA-N 6-methyl-1-(6-methylheptoxy)heptane Chemical compound CC(C)CCCCCOCCCCCC(C)C JJDGTGGQXAAVQX-UHFFFAOYSA-N 0.000 description 5
- 229920003171 Poly (ethylene oxide) Polymers 0.000 description 5
- 239000001569 carbon dioxide Substances 0.000 description 5
- 229960003237 betaine Drugs 0.000 description 4
- 230000005465 channeling Effects 0.000 description 4
- 239000007788 liquid Substances 0.000 description 4
- 239000003513 alkali Substances 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 238000002474 experimental method Methods 0.000 description 3
- 239000003292 glue Substances 0.000 description 3
- 125000002467 phosphate group Chemical group [H]OP(=O)(O[H])O[*] 0.000 description 3
- 239000003381 stabilizer Substances 0.000 description 3
- 238000012360 testing method Methods 0.000 description 3
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 2
- 239000002202 Polyethylene glycol Substances 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 2
- 239000005864 Sulphur Substances 0.000 description 2
- 244000269722 Thea sinensis Species 0.000 description 2
- 150000001336 alkenes Chemical class 0.000 description 2
- 150000001412 amines Chemical class 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 235000009508 confectionery Nutrition 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 230000003247 decreasing effect Effects 0.000 description 2
- LQZZUXJYWNFBMV-UHFFFAOYSA-N dodecan-1-ol Chemical compound CCCCCCCCCCCCO LQZZUXJYWNFBMV-UHFFFAOYSA-N 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 150000002357 guanidines Chemical class 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000002105 nanoparticle Substances 0.000 description 2
- HLERILKGMXJNBU-UHFFFAOYSA-N norvaline betaine Chemical compound CCCC(C([O-])=O)[N+](C)(C)C HLERILKGMXJNBU-UHFFFAOYSA-N 0.000 description 2
- 229920001223 polyethylene glycol Polymers 0.000 description 2
- 229920000642 polymer Polymers 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 150000003839 salts Chemical class 0.000 description 2
- 229920006395 saturated elastomer Polymers 0.000 description 2
- DNIAPMSPPWPWGF-GSVOUGTGSA-N (R)-(-)-Propylene glycol Chemical compound C[C@@H](O)CO DNIAPMSPPWPWGF-GSVOUGTGSA-N 0.000 description 1
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 1
- 235000016068 Berberis vulgaris Nutrition 0.000 description 1
- 241000335053 Beta vulgaris Species 0.000 description 1
- HPXYFVXJWMKVHP-UHFFFAOYSA-N C(CC)SO.C(CCCCCCCCCCC)(=O)N Chemical compound C(CC)SO.C(CCCCCCCCCCC)(=O)N HPXYFVXJWMKVHP-UHFFFAOYSA-N 0.000 description 1
- XICHKUZHYIMXSQ-UHFFFAOYSA-N C(CCCCCCCCCCC)[Mg]C(C1=CC=CC=C1)(C)C Chemical compound C(CCCCCCCCCCC)[Mg]C(C1=CC=CC=C1)(C)C XICHKUZHYIMXSQ-UHFFFAOYSA-N 0.000 description 1
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- IMROMDMJAWUWLK-UHFFFAOYSA-N Ethenol Chemical compound OC=C IMROMDMJAWUWLK-UHFFFAOYSA-N 0.000 description 1
- 229920001732 Lignosulfonate Polymers 0.000 description 1
- AMQJEAYHLZJPGS-UHFFFAOYSA-N N-Pentanol Chemical compound CCCCCO AMQJEAYHLZJPGS-UHFFFAOYSA-N 0.000 description 1
- NGGOVSDVFULNPO-UHFFFAOYSA-N OCCCCC.[F] Chemical compound OCCCCC.[F] NGGOVSDVFULNPO-UHFFFAOYSA-N 0.000 description 1
- 239000004372 Polyvinyl alcohol Substances 0.000 description 1
- 229910004298 SiO 2 Inorganic materials 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- ULUAUXLGCMPNKK-UHFFFAOYSA-N Sulfobutanedioic acid Chemical compound OC(=O)CC(C(O)=O)S(O)(=O)=O ULUAUXLGCMPNKK-UHFFFAOYSA-N 0.000 description 1
- XQXMBCRAZQYYPS-UHFFFAOYSA-N [Na].C(N)(O)=O Chemical compound [Na].C(N)(O)=O XQXMBCRAZQYYPS-UHFFFAOYSA-N 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000003213 activating effect Effects 0.000 description 1
- 150000001298 alcohols Chemical class 0.000 description 1
- 150000003973 alkyl amines Chemical class 0.000 description 1
- 125000000217 alkyl group Chemical group 0.000 description 1
- 239000012298 atmosphere Substances 0.000 description 1
- 239000011449 brick Substances 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 150000001732 carboxylic acid derivatives Chemical class 0.000 description 1
- 239000001913 cellulose Substances 0.000 description 1
- 229920002678 cellulose Polymers 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 239000003599 detergent Substances 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 125000000118 dimethyl group Chemical group [H]C([H])([H])* 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 125000003438 dodecyl group Chemical group [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])* 0.000 description 1
- QCCKPZOPTXCJPL-UHFFFAOYSA-N dodecyl(dimethyl)azanium;hydroxide Chemical compound [OH-].CCCCCCCCCCCC[NH+](C)C QCCKPZOPTXCJPL-UHFFFAOYSA-N 0.000 description 1
- 235000013399 edible fruits Nutrition 0.000 description 1
- 239000004744 fabric Substances 0.000 description 1
- NBVXSUQYWXRMNV-UHFFFAOYSA-N fluoromethane Chemical compound FC NBVXSUQYWXRMNV-UHFFFAOYSA-N 0.000 description 1
- 238000005187 foaming Methods 0.000 description 1
- 229930182478 glucoside Natural products 0.000 description 1
- 238000003306 harvesting Methods 0.000 description 1
- 125000002887 hydroxy group Chemical group [H]O* 0.000 description 1
- MTNDZQHUAFNZQY-UHFFFAOYSA-N imidazoline Chemical compound C1CN=CN1 MTNDZQHUAFNZQY-UHFFFAOYSA-N 0.000 description 1
- 230000008595 infiltration Effects 0.000 description 1
- 238000001764 infiltration Methods 0.000 description 1
- 238000012332 laboratory investigation Methods 0.000 description 1
- 125000000400 lauroyl group Chemical group O=C([*])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
- 229920002521 macromolecule Polymers 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 230000003647 oxidation Effects 0.000 description 1
- 238000007254 oxidation reaction Methods 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 239000013618 particulate matter Substances 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 238000006116 polymerization reaction Methods 0.000 description 1
- 229920002451 polyvinyl alcohol Polymers 0.000 description 1
- 235000019422 polyvinyl alcohol Nutrition 0.000 description 1
- 230000001376 precipitating effect Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 150000003242 quaternary ammonium salts Chemical class 0.000 description 1
- 238000009738 saturating Methods 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- BTURAGWYSMTVOW-UHFFFAOYSA-M sodium dodecanoate Chemical compound [Na+].CCCCCCCCCCCC([O-])=O BTURAGWYSMTVOW-UHFFFAOYSA-M 0.000 description 1
- 229940082004 sodium laurate Drugs 0.000 description 1
- UAJTZZNRJCKXJN-UHFFFAOYSA-M sodium;2-dodecoxy-2-oxoethanesulfonate Chemical compound [Na+].CCCCCCCCCCCCOC(=O)CS([O-])(=O)=O UAJTZZNRJCKXJN-UHFFFAOYSA-M 0.000 description 1
- 239000002904 solvent Substances 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 238000003756 stirring Methods 0.000 description 1
- 238000005728 strengthening Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 description 1
- 230000008719 thickening Effects 0.000 description 1
- 235000020681 well water Nutrition 0.000 description 1
- 239000002349 well water Substances 0.000 description 1
- 239000002888 zwitterionic surfactant Substances 0.000 description 1
- 239000004711 α-olefin Substances 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
Landscapes
- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Geochemistry & Mineralogy (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
Abstract
The invention discloses a kind of raising compact reservoir CO2 to drive the aqueous solution of effect and its preparation method and application method；With the total weight of aqueous solution, which includes: wettability modification agent 0.01-0.2wt%, bleeding agent 0.01-0.1wt%, reduces the surfactant 0.05-0.5wt% of oil water interfacial tension, remaining is water.Technical solution of the present invention is by will be by wettability modification agent, bleeding agent, the raising compact reservoir CO that forms of surfactant for reducing oil water interfacial tension2Drive the aqueous solution and CO of effect2Alternately injection oil reservoir, wettability modification agent change matrix micropores wettability of the surface, can reduce the surfactant molecule of oil water interfacial tension under the promotion of bleeding agent, it infiltrates into matrix micropores, the effects of crude oil is passed through imbibition expels out micropore, reaches in crack, in CO2Displacement under achieve the effect that improve oil recovery factor.
Description
Technical field
The invention belongs to oil field development technical fields, more particularly, to a kind of raising compact reservoir CO2Drive the water of effect
Solution and its preparation method and application method.
Background technique
Current foreign countries CO2It is mature that the displacement of reservoir oil improves oil recovery factor technology, and is widely applied, but CO2Viscosity
Low, displacing front is very sensitive to stickiness fingering, and stickiness fingering makes the CO of injection2The channelling around the oil by displacement, channelling reduce
CO2Sweep efficiency, show as the too early has channeling of certain oil wells on scene, cause that Liquid output decline, gas-oil ratio steeply rises
Phenomenon, so that CO2Utilization rate decline, and increase operating cost.
Foreign countries are directed to CO2Gas during drive is advanced by leaps and bounds along crack to be had conducted extensive research, and is applied in mining site.
Main technology has water alternating gas injection (WAG) method, gel method, foam method etc., and has carried out field application.Water alternating gas injection
Although effectively can inhibit or slow down has channeling, because the permeability difference due to matrix and crack is too big, injection water is caused to be also
It advances by leaps and bounds along crack.CO can be effectively suppressed in gel2Has channeling, but the use of gel is limited by conditions such as reservoir temperature, salinities, simultaneously
Also it is easy to block gas passage.Foam is in external CO2Drive during application it is more, majority success, part failure, mainly by
In the decreased effectiveness of crack foam biggish for scale.Both at home and abroad to CO2Foam foaming agent has carried out a large amount of research and reality
It tramples, especially America & Canada, the alpha-olefin sulphur that lignosulfonates, the USP4393937 introduced such as USP4086964 is introduced
Hydrochlorate, USP4113011 introduce aliphatic alcohol polyethenoxy sulfate, Stepan Chemical Co. Lathanol
The CD1045 etc. of LAL70, Chevrn.Cheng Jiecheng et al. discloses one kind by detergent alkylate sulphur in patent CN101089117
The foaming agent of sour sodium, modified guanidine glue and water composition, for adjusting the gas entry profile of carbon dioxide injection gas well.CN103721625A is situated between
A kind of water base water-soluble macromolecule surfactant continued as foam stabiliser.CN105238380A discloses a kind of oil gas field
With novel inorganic subparticle strengthening foam system, the foaming agent including 0.2~0.8wt%, the novel nothing of 0.5~2.0wt%
Machine subparticle, surplus are water；The novel inorganic subparticle is to trap the thin of partial size≤2.5 μm screened in atmosphere
Particulate matter.CN104140802A describes a kind of gas well water pumping gas production foam discharging agent, and by Gemini surface active agent, (quaternary ammonium salt is double
Sub- surfactant), zwitterionic surfactant (cocoyl amine propyl betaine or lauroyl amine propyl betaine),
High bond energy surfactant (fluorocarbon surfactant) and high molecular polymer (polyacrylamide) mix.CN85102151
A kind of carbon dioxide-base liquid fracturing fluid for pressure break is described, foaming agent therein is glycine betaine, sulphation alcoxyl chemical combination
At least one of object, ethoxylated linear alcohols, quaternary ammonium alkyl, alkyldiethanolamine, oxidation of alkyl amine.CN103980873 is public
A kind of three-phase froth composite oil-displacing system of cloth, foaming agent used are myristyl hydroxy sulfo lycine, cocamidopropyl propyl amide sweet tea
One of dish alkali or combination, foam stabilizing system are the compound system of polymer and frozen glue dispersion.CN105038756 discloses a kind of drive
The carbon dioxide foam systems of oil addition hydrophilic nano particle, mainly by lauryl alcohol polyethylene glycol oxide polyethenoxy ether, hydrophilic
Type nano SiO 2 particle, sodium chloride composition.CN1890346 discloses for being acidified, matrix acidizing, gravel, water conservancy diversion and
The carbon dioxide foaming fluid of cleaning, foaming agent are beet alkali ampholytic surface active agent, dodecyl dimethyl Benzylmagnesium chloride
Ammonium etc..CN101619210 discloses one kind and is suitable for low-permeability oil deposit carbon dioxide foam stabilizer, by modified guanidine glue, hydroxyl second
Base cellulose, lauryl alcohol composition.CN103275693 discloses a kind of acidity CO2The efficient foaming agent of foam fracturing system, carbochain are
Alkyl dimethyl betaine, alkyl sulfo betaines, cetyl hydroxypropyl sulfobetaines and the lauryl alcohol ether glucosides of 16-18
Composition.CN103881683 discloses kind for CO2The foaming agent that has channeling is blocked in the displacement of reservoir oil, by carboxylic acid type imidazoline amophoteric surface
Activating agent, alpha-alkene sulfonate, dodecyldimethylammonium hydroxide inner salt and alkylolamides composition.CN104293334x discloses one
Kind dissolves in CO2Foaming agent and preparation method thereof, consisting of alkyl phenol polyoxyethylene ether, and with ethyl alcohol, amylalcohol, fluorine amylalcohol
As solubilizer.CN104498016A discloses a kind of carbon dioxide drive foaming agent and preparation method thereof, foaming agent composition
For 12 a heatable brick bed base amino carboxylic acid sodium of N- and Shuangzi sodium laurate, foam stabilizer is molecular weight polyethylene glycol 200-6000, gathers
One or two kinds of mixing of vinyl alcohol, modified polyvinylalcohol.CN102746841B disclose it is a kind of based on nano particle with
The stable foam system of Gemini surface active.
Amine salt method, underground polymerization method, the alcohol of also having carried out external simultaneously causes salt precipitating, CO2The envelopes such as thickening alter method, these skills
Art only rests on the in-house laboratory investigation stage, almost without field application is obtained.
Above-mentioned technology is mainly for hypotonic, middle and high infiltration oil reservoir, and for compact oil reservoir, CO2It cannot be introduced into matrix micropores, nothing
Method displaces crude oil therein, and the closure for depending merely on fracture, which can not achieve, improves gas drive effect.
Summary of the invention
Present invention aim to address for compact oil reservoir, CO2It cannot be introduced into matrix micropores, crude oil therein can not be driven
Out, the closure for depending merely on fracture can not achieve the problem of improving gas drive effect；A kind of raising compact reservoir CO is provided2Drive effect
Aqueous solution, to realize the raising of oil recovery.
To achieve the goals above, the first aspect of the present invention provides a kind of raising compact reservoir CO2Drive the water-soluble of effect
Liquid, with the total weight of aqueous solution, which includes: wettability modification agent 0.01-0.2wt%, bleeding agent 0.01-
0.1wt%, reduces the surfactant 0.05-0.5wt% of oil water interfacial tension, remaining is water.
Preferably, with the total weight of aqueous solution, the aqueous solution includes: wettability modification agent 0.02-0.1wt%, is seeped
Saturating agent 0.02-0.08wt%, reduces the surfactant 0.1-0.4wt% of oil water interfacial tension, remaining is water.
Preferably, the wettability modification agent is selected from sodium sulfate of polyethenoxy ether of fatty alcohol, α-sodium olefin sulfonate, lauryl
At least one of sulfosuccinic acid monoester disodium and coconut oil diethanol amide.
Preferably, the wettability modification agent is lauryl sulfosuccinic acid monoester disodium.
Preferably, the bleeding agent is Phosphate of Polyoxyethylene Isooctyl Ether and/or pungent Kui alcohol polyoxyethylene ether phosphate.
Preferably, the surfactant for reducing oil water interfacial tension includes: cocamidopropyl propyl amide hydroxy sulfo lycine
And/or dodecanamide propyl hydroxy sulfo lycine.
Preferably, the water is water flooding, tap water, the surface water or oil reservoir reinjected water；Preferably oil reservoir reinjected water.
The second aspect of the present invention provides a kind of above-mentioned raising compact reservoir CO2The preparation method of the aqueous solution of effect is driven,
The preparation method includes: by water, wettability modification agent, bleeding agent and to reduce the surfactant mixing of oil water interfacial tension
It is even, obtain the raising compact reservoir CO2Drive the aqueous solution of effect.
The third aspect of the present invention provides a kind of above-mentioned raising compact reservoir CO2The application method of the aqueous solution of effect is driven,
The application method includes: that will improve compact reservoir CO2Drive the aqueous solution and CO of effect2Gas alternately injects oil reservoir；
Preferably, injection improves compact reservoir CO2Closing well after the aqueous solution of effect is driven, reinjects CO after 10-72h2Gas.
Technical solution of the present invention by the surface of wettability modification agent, bleeding agent, reduction oil water interfacial tension by that will be lived
Property agent composition raising compact reservoir CO2Drive the aqueous solution and CO of effect2Alternately injection oil reservoir, wettability modification agent are micro- by matrix
The wettability modification of hole surface can reduce the surfactant molecule of oil water interfacial tension under the promotion of bleeding agent, infiltrate into
In matrix micropores, the effects of crude oil is passed through imbibition, expels out micropore, reaches in crack, in CO2Displacement under to reach raising former
The effect of oil recovery.
Other features and advantages of the present invention will then part of the detailed description can be specified.
Detailed description of the invention
Exemplary embodiment of the invention is described in more detail in conjunction with the accompanying drawings, it is of the invention above-mentioned and its
Its purpose, feature and advantage will be apparent, wherein in exemplary embodiment of the invention, identical reference label
Typically represent same parts.
Fig. 1 shows each staggered oil recovery ratio figure of displacement process of test case of the invention.
Specific embodiment
The preferred embodiment of the present invention is described in more detail below.Although the following describe preferred implementations of the invention
Mode, however, it is to be appreciated that may be realized in various forms the present invention without that should be limited by the embodiments set forth herein.Phase
Instead, these embodiments are provided so that the present invention is more thorough and complete, and can be by the scope of the present invention completely
It is communicated to those skilled in the art.
The first aspect of the present invention provides a kind of raising compact reservoir CO2The aqueous solution of effect is driven, with the gross weight of aqueous solution
Meter, the aqueous solution include: wettability modification agent 0.01-0.2wt%, bleeding agent 0.01-0.1wt%, reduce oil-water interfaces
The surfactant 0.05-0.5wt% of power, remaining is water.
In accordance with the present invention it is preferred that the aqueous solution includes: wettability modification agent 0.02- with the total weight of aqueous solution
0.1wt%, bleeding agent 0.02-0.08wt%, reduce the surfactant 0.1-0.4wt% of oil water interfacial tension, remaining is water.
The present invention is primarily directed to implementation CO2The compact reservoir of drive, the more fracturing productions of such reservoir or primary microcrack hair
It educates, infuses CO2When, gas is walked along crack, and to the difference that involves of matrix, saturation has grease, CO in former base matter2It is not easily accessible, cannot achieve
Effective displacement.
Infuse CO2In displacement process, alternating injects raising compact reservoir CO of the invention2The aqueous solution for driving effect, can change
Become wetability, reduce capillary force；Raising compact reservoir CO of the invention2When the aqueous solution of drive effect flows in crack, surface
Active agent molecule diffuses in the micropore of dense matrix, changes the wetability of micropore, reduces the capillary of liquid outflow micropore
Resistance makes grease therein in CO2It is liable to flow out crack under the action of drive pressure, to improve CO2Drive effect.
In accordance with the present invention it is preferred that the wettability modification agent is selected from sodium sulfate of polyethenoxy ether of fatty alcohol (AES), α-
At least one of sodium olefin sulfonate (AOS), lauryl sulfosuccinic acid monoester disodium and coconut oil diethanol amide.
In accordance with the present invention it is preferred that the wettability modification agent is lauryl sulfosuccinic acid monoester disodium.
In accordance with the present invention it is preferred that the bleeding agent is Phosphate of Polyoxyethylene Isooctyl Ether and/or pungent Kui alcohol polyoxy second
Alkene ether phosphate.
In accordance with the present invention it is preferred that the surfactant for reducing oil water interfacial tension includes: cocamidopropyl propyl amide hydroxyl
Sulfobetaines and/or dodecanamide propyl hydroxy sulfo lycine.
In accordance with the present invention it is preferred that the water is water flooding, tap water, the surface water or oil reservoir reinjected water；Preferably oil reservoir
Reinjected water.
The second aspect of the present invention provides a kind of above-mentioned raising compact reservoir CO2The preparation method of the aqueous solution of effect is driven,
The preparation method includes: by water, wettability modification agent, bleeding agent and to reduce the surfactant mixing of oil water interfacial tension
It is even, obtain the raising compact reservoir CO2Drive the aqueous solution of effect.
Preferably, the surface for sequentially adding water, wettability modification agent, bleeding agent and reduction oil water interfacial tension is living
Property agent, it is every a kind of chemical agent is added after be sufficiently stirred, a kind of lower chemical agent is added after added chemical agent is completely dissolved, until
All components, which add, ultimately forms uniform, transparent aqueous solution, the as described raising compact reservoir CO2Drive the aqueous solution of effect.
Preferably, raising compact reservoir CO of the invention is prepared2The each component for driving the aqueous solution of effect can be with
It is commercially available.
The third aspect of the present invention provides a kind of above-mentioned raising compact reservoir CO2The application method of the aqueous solution of effect is driven,
The application method includes: that will improve compact reservoir CO2Drive the aqueous solution and CO of effect2Gas alternately injects oil reservoir；
In accordance with the present invention it is preferred that injection improves compact reservoir CO2Closing well after the aqueous solution of effect is driven, after 10-72h again
Inject CO2Gas.
Closing well reinjects CO afterwards for a period of time after injecting aqueous solution of the invention2Gas helps to improve CO2Effect is driven, into
And improve oil recovery factor.
The present invention is further illustrated by the following examples:
Embodiment 1
The present embodiment provides a kind of raising compact reservoir CO2The aqueous solution of effect is driven, with the total weight of aqueous solution, the water
Solution includes: wettability modification agent 0.1wt%, and bleeding agent 0.03wt% reduces the surfactant of oil water interfacial tension
0.4wt%, remaining is water；Wherein, the wettability modification agent is lauryl sulfosuccinic acid monoester disodium, and the bleeding agent is
Phosphate of Polyoxyethylene Isooctyl Ether, the surfactant for reducing oil water interfacial tension are cocamidopropyl propyl amide hydroxyl sulfo group sweet tea
Dish alkali and dodecanamide propyl hydroxy sulfo lycine, the cocamidopropyl propyl amide hydroxy sulfo lycine and dodecanamide propyl hydroxyl sulphur
The mass ratio of base glycine betaine is 1:1, and the water is oil reservoir reinjected water, salinity 14000mg/L.
The preparation method comprises the following steps: water is successively added into stirring container, wettability modification agent, bleeding agent, reduces oil-water interfaces
The surfactant of power, it is every a kind of chemical agent is added after be sufficiently stirred, add lower one kind after added chemical agent is completely dissolved
Chemical agent, until all components add and ultimately form uniform, transparent aqueous solution, the as described raising compact reservoir CO2Drive effect
The aqueous solution of fruit.
Embodiment 2
The present embodiment provides a kind of raising compact reservoir CO2The aqueous solution of effect is driven, with the total weight of aqueous solution, the water
Solution includes: wettability modification agent 0.03wt%, and bleeding agent 0.07wt% reduces the surfactant of oil water interfacial tension
0.15wt%, remaining is water；Wherein, the wettability modification agent is lauryl sulfosuccinic acid monoester disodium, the bleeding agent
For pungent Kui alcohol polyoxyethylene ether phosphate, the surfactant for reducing oil water interfacial tension is cocamidopropyl propyl amide hydroxyl sulfo group
Glycine betaine, the water are oil reservoir reinjected water, salinity 14000mg/L.
The preparation method is the same as that of Example 1.
Embodiment 3
The present embodiment provides a kind of raising compact reservoir CO2The aqueous solution of effect is driven, with the total weight of aqueous solution, the water
Solution includes: wettability modification agent 0.06wt%, and bleeding agent 0.04wt% reduces the surfactant of oil water interfacial tension
0.25wt%, remaining is water；Wherein, the wettability modification agent is lauryl sulfosuccinic acid monoester disodium, the bleeding agent
For Phosphate of Polyoxyethylene Isooctyl Ether and Xin Kui alcohol polyoxyethylene ether phosphate, the Phosphate of Polyoxyethylene Isooctyl Ether and
The mass ratio of pungent Kui alcohol polyoxyethylene ether phosphate is 1:1, and the surfactant for reducing oil water interfacial tension is lauroyl
Amine hydroxysultaine, the water are oil reservoir reinjected water, salinity 14000mg/L.
The preparation method is the same as that of Example 1.
Embodiment 4
The wettability modification agent that is distinguished as of the present embodiment and embodiment 1 is sodium sulfate of polyethenoxy ether of fatty alcohol,
His each component and dosage and preparation method are same as Example 1.
Embodiment 5
The wettability modification agent that is distinguished as of the present embodiment and embodiment 1 is 0.18wt%, bleeding agent 0.02wt%,
Reduce oil water interfacial tension surfactant be 0.48wt%, other each components and dosage and preparation method with embodiment 1
It is identical.
Test case
The raising compact reservoir CO prepared using embodiment 1-52The aqueous solution for driving effect carries out oil displacement experiment, measures crude oil
Recovery ratio, the temperature of oil displacement experiment are 70 DEG C, and specific experiment process is as follows:
Saturated oils is perfused in testing model used, saturated oils used is the crude oil of northeast branch company, is 60 DEG C in temperature
When, back pressure 6MPa；
Water drive is carried out to petrophysical model first, displacement to moisture content is greater than 98%；Then CO is carried out2It is driven to oil-free outflow；
The aqueous solution 0.8PV for re-injecting embodiment seals model both ends, bored well 18 hours；Finally re-inject CO2, carry out CO2
It drives.
Experimental result: displacement pressure difference starts higher during water drive, decreased later to steady, be due to after crude oil starting,
Oil saturation constantly reduces, and the later period is basically unchanged；
As shown in Figure 1, waterflood recovery efficiency factor reaches 48.0% in terms of recovery ratio, CO is then infused2Effect very little, recovery ratio is only
Have 1.8%, then infuses the raising compact reservoir CO of embodiment 12The aqueous solution for driving effect has micro crude oil to flow out in the process, this mistake
Journey recovery ratio 0.71%；After the aqueous solution injection of embodiment 1, CO is infused again2, this process recovery ratio is 4.61%.Pass through
Front and back CO twice2The variation of the oil recovery factor of drive, it is seen that raising compact reservoir CO of the invention2The aqueous solution for driving effect is realized
In CO2Displacement under achieve the effect that improve oil recovery factor.
Table 1
As known to table 1, in terms of recovery ratio, waterflood recovery efficiency factor reaches 47.1-48.5%, then infuses CO2Effect very little, harvesting
Rate only has 1.75-1.96%, then infuses the raising compact reservoir CO of embodiment2The aqueous solution for driving effect has micro crude oil in the process
Outflow, this process recovery ratio 0.69-0.78%；After the aqueous solution injection of embodiment, CO is infused again2, this process recovery ratio
For 3.85-4.61%.Pass through front and back CO twice2The variation of the oil recovery factor of drive, it is seen that raising compact reservoir CO of the invention2
The aqueous solution for driving effect is realized in CO2Displacement under achieve the effect that improve oil recovery factor；Simultaneously from the water of each embodiment
After solution injection, CO is infused again2, the numerical value comparison of this process recovery ratio is it is found that the aqueous solution raising crude oil of embodiment 1-3 is adopted
The effect of yield is better than embodiment 4-5.
Various embodiments of the present invention are described above, above description is exemplary, and non-exclusive, and
It is not limited to disclosed each embodiment.Without departing from the scope and spirit of illustrated each embodiment, for this skill
Many modifications and changes are obvious for the those of ordinary skill in art field.
Claims (10)
1. a kind of raising compact reservoir CO2Drive the aqueous solution of effect, which is characterized in that with the total weight of aqueous solution, the aqueous solution
It include: wettability modification agent 0.01-0.2wt%, bleeding agent 0.01-0.1wt% reduces the surfactant of oil water interfacial tension
0.05-0.5wt%, remaining is water.
2. raising compact reservoir CO according to claim 12Drive the aqueous solution of effect, wherein with the total weight of aqueous solution
Meter, the aqueous solution include: wettability modification agent 0.02-0.1wt%, bleeding agent 0.02-0.08wt%, reduce oil-water interfaces
The surfactant 0.1-0.4wt% of power, remaining is water.
3. raising compact reservoir CO according to claim 1 or 22Drive the aqueous solution of effect, wherein the wettability modification
Agent is selected from sodium sulfate of polyethenoxy ether of fatty alcohol, α-sodium olefin sulfonate, lauryl sulfosuccinic acid monoester disodium and coconut oil two
At least one of glycollic amide.
4. raising compact reservoir CO according to claim 1 or 22Drive the aqueous solution of effect, wherein the wettability modification
Agent is lauryl sulfosuccinic acid monoester disodium.
5. raising compact reservoir CO according to claim 1 or 22Drive the aqueous solution of effect, wherein the bleeding agent is different
Octanol polyoxyethylene ether phosphate and/or pungent Kui alcohol polyoxyethylene ether phosphate.
6. raising compact reservoir CO according to claim 1 or 22Drive the aqueous solution of effect, wherein reduction grease circle
The surfactant of face tension includes: cocamidopropyl propyl amide hydroxy sulfo lycine and/or dodecanamide propyl hydroxy sulfo lycine.
7. raising compact reservoir CO according to claim 1 or 22Drive effect aqueous solution, wherein the water be water flooding,
Tap water, the surface water or oil reservoir reinjected water；Preferably oil reservoir reinjected water.
8. raising compact reservoir CO described in any one of claim 1-72The preparation method of the aqueous solution of effect is driven, it is special
Sign is that the preparation method includes: by water, wettability modification agent, bleeding agent and the surfactant for reducing oil water interfacial tension
It is uniformly mixed, obtains the raising compact reservoir CO2Drive the aqueous solution of effect.
9. raising compact reservoir CO described in any one of claim 1-72The application method of the aqueous solution of effect is driven, it is special
Sign is that the application method includes: that will improve compact reservoir CO2Drive the aqueous solution and CO of effect2Gas alternately injects oil reservoir.
10. application method according to claim 9, wherein injection improves compact reservoir CO2It is closed after driving the aqueous solution of effect
Well reinjects CO after 10-72h2Gas.
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