CN105154051B - Pressure-reducing injection-increasing surfactant compound composition and preparation method and application thereof - Google Patents
Pressure-reducing injection-increasing surfactant compound composition and preparation method and application thereof Download PDFInfo
- Publication number
- CN105154051B CN105154051B CN201510622029.8A CN201510622029A CN105154051B CN 105154051 B CN105154051 B CN 105154051B CN 201510622029 A CN201510622029 A CN 201510622029A CN 105154051 B CN105154051 B CN 105154051B
- Authority
- CN
- China
- Prior art keywords
- compound composition
- surfactant compound
- water
- injection
- pressure
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 239000000203 mixture Substances 0.000 title claims abstract description 130
- 239000004094 surface-active agent Substances 0.000 title claims abstract description 114
- 150000001875 compounds Chemical class 0.000 title claims abstract description 111
- 238000002360 preparation method Methods 0.000 title claims abstract description 11
- 238000002347 injection Methods 0.000 claims abstract description 118
- 239000007924 injection Substances 0.000 claims abstract description 118
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 102
- 239000004927 clay Substances 0.000 claims abstract description 18
- 230000035699 permeability Effects 0.000 claims abstract description 17
- 239000002280 amphoteric surfactant Substances 0.000 claims abstract description 12
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 11
- 239000002994 raw material Substances 0.000 claims abstract description 11
- 239000003381 stabilizer Substances 0.000 claims abstract description 9
- 239000000243 solution Substances 0.000 claims description 32
- 229920001577 copolymer Polymers 0.000 claims description 19
- 229920006317 cationic polymer Polymers 0.000 claims description 17
- ROSDSFDQCJNGOL-UHFFFAOYSA-N Dimethylamine Chemical compound CNC ROSDSFDQCJNGOL-UHFFFAOYSA-N 0.000 claims description 12
- KWIUHFFTVRNATP-UHFFFAOYSA-N glycine betaine Chemical group C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 claims description 12
- 238000006243 chemical reaction Methods 0.000 claims description 11
- FPYJFEHAWHCUMM-UHFFFAOYSA-N maleic anhydride Chemical compound O=C1OC(=O)C=C1 FPYJFEHAWHCUMM-UHFFFAOYSA-N 0.000 claims description 10
- BAPJBEWLBFYGME-UHFFFAOYSA-N Methyl acrylate Chemical compound COC(=O)C=C BAPJBEWLBFYGME-UHFFFAOYSA-N 0.000 claims description 8
- 230000015572 biosynthetic process Effects 0.000 claims description 8
- -1 hydroxy sulfo lycine Chemical compound 0.000 claims description 8
- 230000006837 decompression Effects 0.000 claims description 7
- 238000011049 filling Methods 0.000 claims description 7
- JPZROSNLRWHSQQ-UHFFFAOYSA-N furan-2,5-dione;prop-2-enoic acid Chemical compound OC(=O)C=C.O=C1OC(=O)C=C1 JPZROSNLRWHSQQ-UHFFFAOYSA-N 0.000 claims description 7
- 229920001897 terpolymer Polymers 0.000 claims description 7
- 239000003129 oil well Substances 0.000 claims description 6
- 238000003756 stirring Methods 0.000 claims description 6
- 125000003368 amide group Chemical group 0.000 claims description 5
- 229960003237 betaine Drugs 0.000 claims description 5
- 125000001183 hydrocarbyl group Chemical group 0.000 claims description 4
- JIGUQPWFLRLWPJ-UHFFFAOYSA-N Ethyl acrylate Chemical compound CCOC(=O)C=C JIGUQPWFLRLWPJ-UHFFFAOYSA-N 0.000 claims description 3
- 230000003190 augmentative effect Effects 0.000 claims description 3
- CQEYYJKEWSMYFG-UHFFFAOYSA-N butyl acrylate Chemical compound CCCCOC(=O)C=C CQEYYJKEWSMYFG-UHFFFAOYSA-N 0.000 claims description 3
- LYRFLYHAGKPMFH-UHFFFAOYSA-N octadecanamide Chemical compound CCCCCCCCCCCCCCCCCC(N)=O LYRFLYHAGKPMFH-UHFFFAOYSA-N 0.000 claims description 3
- PNJWIWWMYCMZRO-UHFFFAOYSA-N pent‐4‐en‐2‐one Natural products CC(=O)CC=C PNJWIWWMYCMZRO-UHFFFAOYSA-N 0.000 claims description 3
- 229920000642 polymer Polymers 0.000 claims description 3
- 239000002253 acid Substances 0.000 claims description 2
- 239000000654 additive Substances 0.000 claims description 2
- 230000000996 additive effect Effects 0.000 claims description 2
- 150000002892 organic cations Chemical class 0.000 claims 2
- 239000004593 Epoxy Substances 0.000 claims 1
- ZXYFGZNMDRNOGQ-UHFFFAOYSA-N ac1lawgt Chemical compound [S]O ZXYFGZNMDRNOGQ-UHFFFAOYSA-N 0.000 claims 1
- 150000001335 aliphatic alkanes Chemical class 0.000 claims 1
- 150000001336 alkenes Chemical class 0.000 claims 1
- 150000001408 amides Chemical group 0.000 claims 1
- 238000010538 cationic polymerization reaction Methods 0.000 claims 1
- VIRPUNZTLGQDDV-UHFFFAOYSA-N chloro propanoate Chemical compound CCC(=O)OCl VIRPUNZTLGQDDV-UHFFFAOYSA-N 0.000 claims 1
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 claims 1
- JRZJOMJEPLMPRA-UHFFFAOYSA-N olefin Natural products CCCCCCCC=C JRZJOMJEPLMPRA-UHFFFAOYSA-N 0.000 claims 1
- 239000003921 oil Substances 0.000 abstract description 66
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 abstract description 10
- 238000004945 emulsification Methods 0.000 abstract description 8
- 230000006378 damage Effects 0.000 abstract description 7
- 239000010779 crude oil Substances 0.000 abstract description 6
- 229910000019 calcium carbonate Inorganic materials 0.000 abstract description 5
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 abstract description 4
- 230000009286 beneficial effect Effects 0.000 abstract description 3
- 230000007774 longterm Effects 0.000 abstract description 2
- 239000002244 precipitate Substances 0.000 abstract 1
- 238000006073 displacement reaction Methods 0.000 description 16
- 239000011435 rock Substances 0.000 description 12
- 230000000694 effects Effects 0.000 description 11
- 238000002474 experimental method Methods 0.000 description 10
- 230000008859 change Effects 0.000 description 9
- ILRSCQWREDREME-UHFFFAOYSA-N dodecanamide Chemical compound CCCCCCCCCCCC(N)=O ILRSCQWREDREME-UHFFFAOYSA-N 0.000 description 8
- 238000000034 method Methods 0.000 description 7
- 239000002245 particle Substances 0.000 description 6
- LRWZZZWJMFNZIK-UHFFFAOYSA-N 2-chloro-3-methyloxirane Chemical compound CC1OC1Cl LRWZZZWJMFNZIK-UHFFFAOYSA-N 0.000 description 5
- 230000000903 blocking effect Effects 0.000 description 5
- 239000007788 liquid Substances 0.000 description 5
- 239000013589 supplement Substances 0.000 description 5
- 239000003513 alkali Substances 0.000 description 4
- 230000007423 decrease Effects 0.000 description 4
- 230000005764 inhibitory process Effects 0.000 description 4
- 229910052901 montmorillonite Inorganic materials 0.000 description 4
- 238000012360 testing method Methods 0.000 description 4
- 241000894006 Bacteria Species 0.000 description 3
- 208000027418 Wounds and injury Diseases 0.000 description 3
- 230000003213 activating effect Effects 0.000 description 3
- 239000002734 clay mineral Substances 0.000 description 3
- 238000000151 deposition Methods 0.000 description 3
- 230000008021 deposition Effects 0.000 description 3
- GUJOJGAPFQRJSV-UHFFFAOYSA-N dialuminum;dioxosilane;oxygen(2-);hydrate Chemical group 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 description 3
- 239000012530 fluid Substances 0.000 description 3
- 208000014674 injury Diseases 0.000 description 3
- 238000005259 measurement Methods 0.000 description 3
- 239000011148 porous material Substances 0.000 description 3
- 238000001556 precipitation Methods 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- 235000020681 well water Nutrition 0.000 description 3
- 239000002349 well water Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- 241000295146 Gallionellaceae Species 0.000 description 2
- PLZVEHJLHYMBBY-UHFFFAOYSA-N Tetradecylamine Chemical compound CCCCCCCCCCCCCCN PLZVEHJLHYMBBY-UHFFFAOYSA-N 0.000 description 2
- 241001122767 Theaceae Species 0.000 description 2
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 2
- OSGAYBCDTDRGGQ-UHFFFAOYSA-L calcium sulfate Chemical compound [Ca+2].[O-]S([O-])(=O)=O OSGAYBCDTDRGGQ-UHFFFAOYSA-L 0.000 description 2
- 238000004364 calculation method Methods 0.000 description 2
- 235000009508 confectionery Nutrition 0.000 description 2
- 239000003814 drug Substances 0.000 description 2
- 235000014413 iron hydroxide Nutrition 0.000 description 2
- NCNCGGDMXMBVIA-UHFFFAOYSA-L iron(ii) hydroxide Chemical compound [OH-].[OH-].[Fe+2] NCNCGGDMXMBVIA-UHFFFAOYSA-L 0.000 description 2
- 239000003350 kerosene Substances 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 244000005700 microbiome Species 0.000 description 2
- 238000005325 percolation Methods 0.000 description 2
- 239000000843 powder Substances 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- 238000004088 simulation Methods 0.000 description 2
- 230000006641 stabilisation Effects 0.000 description 2
- 238000011105 stabilization Methods 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 230000008961 swelling Effects 0.000 description 2
- 230000001052 transient effect Effects 0.000 description 2
- YFVKHKCZBSGZPE-UHFFFAOYSA-N 1-(1,3-benzodioxol-5-yl)-2-(propylamino)propan-1-one Chemical compound CCCNC(C)C(=O)C1=CC=C2OCOC2=C1 YFVKHKCZBSGZPE-UHFFFAOYSA-N 0.000 description 1
- 238000007445 Chromatographic isolation Methods 0.000 description 1
- OFOBLEOULBTSOW-UHFFFAOYSA-N Propanedioic acid Natural products OC(=O)CC(O)=O OFOBLEOULBTSOW-UHFFFAOYSA-N 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 125000002252 acyl group Chemical group 0.000 description 1
- 239000012736 aqueous medium Substances 0.000 description 1
- 238000003556 assay Methods 0.000 description 1
- 210000000481 breast Anatomy 0.000 description 1
- 150000001768 cations Chemical class 0.000 description 1
- 238000013329 compounding Methods 0.000 description 1
- 238000007334 copolymerization reaction Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 235000013399 edible fruits Nutrition 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000005189 flocculation Methods 0.000 description 1
- 230000016615 flocculation Effects 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 239000003292 glue Substances 0.000 description 1
- 239000004519 grease Substances 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- VZCYOOQTPOCHFL-UPHRSURJSA-N maleic acid Chemical compound OC(=O)\C=C/C(O)=O VZCYOOQTPOCHFL-UPHRSURJSA-N 0.000 description 1
- 239000011976 maleic acid Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 210000003097 mucus Anatomy 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 239000005416 organic matter Substances 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 230000003449 preventive effect Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 238000009738 saturating Methods 0.000 description 1
- 239000002455 scale inhibitor Substances 0.000 description 1
- 239000013049 sediment Substances 0.000 description 1
- 230000035945 sensitivity Effects 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 239000003583 soil stabilizing agent Substances 0.000 description 1
- 239000002904 solvent Substances 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- VZCYOOQTPOCHFL-UHFFFAOYSA-N trans-butenedioic acid Natural products OC(=O)C=CC(O)=O VZCYOOQTPOCHFL-UHFFFAOYSA-N 0.000 description 1
- 230000005514 two-phase flow Effects 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
- 230000010148 water-pollination Effects 0.000 description 1
- 238000009736 wetting 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
-
- 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
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/528—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/882—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/12—Swell inhibition, i.e. using additives to drilling or well treatment fluids for inhibiting clay or shale swelling or disintegrating
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Inorganic Chemistry (AREA)
- Emulsifying, Dispersing, Foam-Producing Or Wetting Agents (AREA)
Abstract
The invention provides a pressure-reducing and injection-increasing surfactant compound composition and a preparation method and application thereof. The raw material components of the pressure-reducing injection-increasing surfactant compound composition comprise, by weight, 0.05-0.2 part of amphoteric surfactant, 0.05-0.15 part of clay stabilizer, 0.005-0.012 part of antiscaling agent and 100 parts of water. The invention also provides a preparation method and application of the pressure-reducing injection-increasing surfactant compound composition. The pressure-reducing injection-increasing surfactant compound composition is used for the pressure-reducing injection-increasing of a water injection well with ultra-low permeability and ultra-low permeability oil reservoirs and long-term high-pressure under-injection, can effectively reduce the water injection pressure of the water injection well, and reduces the oil-water interfacial tension to 10 by changing the wettability‑1‑10‑2The mN/m is beneficial to starting of residual oil, can avoid the increase of water injection pressure caused by emulsification of the compound composition on crude oil, improves the water injection capability of an under-injection well, and can prevent clay expansion and inhibit the damage of carbonate precipitates such as calcium carbonate to a stratum.
Description
Technical field
The invention belongs to oilfield exploitation technical fields, and in particular to a kind of increasing injection surfactant compound composition and
Its preparation method.
Background technology
In recent years, low permeability oil field is increasingly becoming the main battle ground of oil field development.Since low permeability reservoir deposited particles are thin, mud
Matter content is high, and hole individual is small, duct is thin, micropore is more, and capillary force effect significantly waits physical property characteristics.With waterflooding extraction,
Water injection well often occur water injection pressure height, difficult water injection in addition stop note the problems such as, stratum energy cannot supplement, and seriously affect
Oil field normally produces.
Low permeability reservoir shorts main cause and comes from blocking.Common blocking type has following several：
(1) water sensitivity blocks：Clay mineral generates the wild effects such as expansion, scattered or flocculation after having chance water.Clay
Expansion depends primarily upon clay mineral type, clay mineral exchangeable cation composition, the ion composition of aqueous medium and concentration.When
Clay is met water and is expanded, and when occupying pore throat volume, seriously reduces permeability.
(2) fine migration blocks：The particle that can migrate include formation crude has free particle, can freely migrate clay particle and
Foreign particle.If flow velocity increases, these particles are migrated, and are blocked fluid flowing passage, are caused permeability decrease.
(3) water blocking damage：When water blocking damage refers mainly to driving force deficiency counteracting capillary force, oil stream card section at pore throat,
Dispersed oil droplets are formed, filtrational resistance is caused to increase, in addition, when water-oil phase flows in the earth formation, when the substantial amounts of emulsion of appearance
During drop, when these drops flow through smaller throat, be hampered deformation, forms additional drag.
(4) fouling and clogging：When reservoir fluid and outside fluid are incompatible, organic matter precipitation or inorganic matter precipitation are generated.It is heavy
Absorption of forming sediment forms dirt in rock surface, and duct is caused to reduce or moved with liquid stream and blocks flow channel, causes the serious damage of reservoir
Evil.Common precipitation has calcium carbonate, barium sulfate, iron hydroxide and calcium sulfate etc..
(5) microorganism clogging：It is to form microorganism that iron bacteria, mucus in oil-field flooding, which form bacterium and sulfate reducing bacteria,
The main contributor of blocking.Iron bacteria and Xi Shi shank bacterium etc. can make the ferrous compound in water be oxidized to iron hydroxide and deposit,
Cause serious blockage problem.
(6) wettability reversal：Surface reactive material is adsorbed onto rock surface, rock wettability can be made to change, very
To wettability reversal, after wettability reversal, water becomes non-wetted phase by original wetting phase, and capillary force becomes the resistance that water enters rock
Power, the rock that water will enter near shaft bottom must first overcome certain door pressure, when producing pressure differential less than door pressure,
Water cannot enter shaft bottom, result in blockage.
In this regard, domestic generally take adds in Chemical composition that, especially surfactant in water is injected, carry out improving ecology
Effect.
However, two kinds and more than surfactant compound composition due to chromatographic isolation, may in actual application
Preferable waterflooding effect is hardly resulted in, when interfacial tension is reduced to ultralow (10-3MN/m or 10-4When mN/m), easily cause breast
Change, although emulsification is conducive to the displacement of reservoir oil, a large amount of emulsifications easily cause water injection pressure to raise, to long-term high pressure under-injected well very not
Profit；The injectant that chemical system is more single, such as active water are taken, performance is often again insufficient.
The content of the invention
Based on above-mentioned the technical issues of occurring, it is an object of the invention to provide a kind of increasing injection surfactant compounds
Composition.The complex composition can be effectively reduced injection pressure, avoid causing crude oil largely emulsification from causing note
Water pressure raises, and improves under-injected well water injection capacity, while can also change wetability, prevent clay swell, reduce capillary force, weaken
Liquid lock effect inhibits the injuries of the carbonate depositions to stratum such as calcium carbonate.
The present invention also aims to provide the preparation method of above-mentioned increasing injection surfactant compound composition, pass through
Increasing injection surfactant compound composition is effectively prepared in the preparation method.
The present invention also aims to provide above-mentioned increasing injection surfactant compound composition as injection water addition
Application of the agent on under-injected well.
In order to achieve the above object, the present invention provides a kind of increasing injection surfactant compound composition, with weight
Part meter, raw material components include 0.05-0.2 parts of amphoteric surfactant, 0.05-0.15 parts of clay stabilizer, scale preventative
0.005-0.012 parts, 100 parts of water.
In above-mentioned surfactant compound composition, it is preferable that the amphoteric surfactant is betaine type amphoteric table
Face activating agent.
In above-mentioned surfactant compound composition, it is preferable that the clay stabilizer is organic cationic polymer.
In above-mentioned surfactant compound composition, it is preferable that the scale preventative is water soluble polymeric scale preventative.
In above-mentioned surfactant compound composition, it is preferable that the water injects water for oil field.
In above-mentioned surfactant compound composition, it is preferable that the betaine type amphoteric surfac-tant is to contain acyl
The hydroxy sulfo lycine of amido, structural formula are as follows：
Wherein, R3For the C of amide groups substitution15-C28Long chain hydrocarbon groups, R1And R2It is C1-C3Short-chain hydrocarbon group；More preferably
Ground, the hydroxy sulfo lycine containing amide groups include dodecanamide propyl hydroxy sulfo lycine, myristyl amide propyl
One or more combinations in hydroxy sulfo lycine, octadecyl amide hydroxysultaine.
In above-mentioned surfactant compound composition, it is preferable that the organic cationic polymer is organic for quaternary
Cationic polymer；It is further preferred that the quaternary organic cationic polymer is epichlorohydrin-dimethylamine cation
Polymer, epoxychloropropane and dimethylamine molar ratio are 1.5 in the Epicholorohydrin-dimethylamine Cationic Polymer:1.
In above-mentioned surfactant compound composition, it is preferable that the water soluble polymeric scale preventative include maleic acid-
Acrylic type copolymer and/or maleic acid anhydride-propenoic acid type copolymer；It is further preferred that the maleic-acrylic acid type copolymerization
Object and/or maleic acid anhydride-propenoic acid type copolymer include maleic acid anhydride-propenoic acid methyl terpolymer, maleic acid anhydride-propenoic acid second
One or more combinations in ester copolymer, maleic acid anhydride-propenoic acid acrylate copolymer；It is further preferred that the maleic acid
In acid anhydride-methyl acrylate copolymer, the molar ratio of maleic anhydride and methyl acrylate is 3:2, the maleic acid anhydride-propenoic acid second
In ester copolymer, the molar ratio of maleic anhydride and ethyl acrylate is 3:2, in the maleic acid anhydride-propenoic acid acrylate copolymer,
The molar ratio of maleic anhydride and butyl acrylate is 3:2.
In the solution of above-mentioned surfactant compound composition, with amphoteric surfactant, clay stabilizer and scale preventative
As solute, water is as solvent.
The present invention also provides the preparation method of above-mentioned increasing injection surfactant compound composition, the preparation method bags
Include following steps：
(1) in atmospheric conditions, amphoteric surfactant, clay stabilizer, scale preventative are taken in reaction kettle；
(2) water is added in into reaction kettle and is heated to 50 DEG C -70 DEG C, stirring is sufficiently uniformly dissolved it, is prepared
State increasing injection surfactant compound composition.
It is being shorted the present invention also provides above-mentioned increasing injection surfactant compound composition as injection water additive
Application on well, includes the following steps：
When the effective connected oil wells moisture content of water filling well group is 50%-70%, the table of more than 0.1PV is continuously injected into well
The solution of face activating agent complex composition in the solution of the surfactant compound composition, with amphoteric surfactant, glues
As solute, total percentage composition of solute is 0.05wt%-0.2wt% for soil stabilizer and scale preventative.
Specific embodiment according to the present invention, by above-mentioned surface-active complex composition with when on under-injected well, it is excellent
Selection of land, the injection rate of the solution of surfactant compound composition is 0.1-0.3PV.
Specific embodiment according to the present invention, by above-mentioned surface-active complex composition with when on under-injected well,
In, when oil pressure or pump pressure within formation fracture pressure 1MPa when, in the solution of surfactant compound composition, solute
Percent of total content be 0.05wt%-0.1wt%；
When oil pressure or pump pressure are more than or equal to 1MPa apart from formation fracture pressure, in the molten of surfactant compound composition
In liquid, the percent of total content of solute is 0.1wt%-0.2wt%.
The increasing injection surfactant compound composition of the present invention is the special low, Oil in Super-low Permeability less than 5mD for permeability
Saturating oil reservoir.
The beneficial effects of the invention are as follows：
The increasing injection surfactant compound composition can change wetability, reduce oil water interfacial tension to 10-1mN/
The m orders of magnitude, Transient interfacial tension can be reduced to 10-2The mN/m orders of magnitude so not only improve the startup of residual oil, and can keep away
Exempt from complex composition crude oil is caused to emulsify and causes water injection pressure rise, is effectively reduced injection pressure, improve and owe
Well water injection capacity is noted, while can also prevent clay swell, inhibit the injuries of the carbonate depositions to stratum such as calcium carbonate.The decompression increases
Note surfactant compound composition can also be such that oil-wet core changes to hydrophilic direction, improve water phase permeability, water-oil phase
Permeation scope broadens, and fettering oily saturation degree reduces, and improves recovery ratio.By acting on above, which answers
It can play the role of reduction water injection pressure with composition, improve water injection rate, average pressure gradients are effectively reduced.
Description of the drawings
Fig. 1 reduces oil water interfacial tension graph for increasing injection surfactant compound composition；
Fig. 2 prevents swollen graph for increasing injection surfactant compound composition；
Fig. 3 is increasing injection surfactant compound composition antiscale graph；
Fig. 4 is increasing injection surfactant compound composition phase percolation curve figure；
Fig. 5 is increasing injection surfactant compound composition drawdown curve figure；
Barometric gradient is injected when Fig. 6 is the 0.3wt% surfactant compound composition displacement of reservoir oils with injection rate change curve；
Barometric gradient is injected when Fig. 7 is the 0.2wt% surfactant compound composition displacement of reservoir oils with injection rate change curve；
Barometric gradient is injected when Fig. 8 is the 0.05wt% surfactant compound composition displacement of reservoir oils with injection rate change curve
Figure.
Specific embodiment
In order to which technical characteristic, purpose and the advantageous effect to the present invention are more clearly understood, now to the skill of the present invention
Art scheme carry out it is described further below, but it is not intended that the present invention can practical range restriction.
Embodiment 1
The present embodiment provides a kind of increasing injection surfactant compound compositions, in parts by weight, raw material components bag
It includes：
Dodecanamide propyl hydroxy sulfo lycine：0.15 part；
Epicholorohydrin-dimethylamine Cationic Polymer：0.088 part of (wherein, molar ratio of epoxychloropropane and dimethylamine
For 1.5:1)；
Maleic acid anhydride-propenoic acid methyl terpolymer：0.012 part (wherein, the molar ratio of maleic anhydride and methyl acrylate is
3:2)；
Oil field injection water：100 parts.
The increasing injection surfactant compound composition of the present embodiment is prepared via a method which to obtain：
In atmospheric conditions, according to raw material components parts by weight meter, the dodecanamide propyl hydroxyl sulfobetaines of 0.15g are weighed
Alkali, the Epicholorohydrin-dimethylamine Cationic Polymer of 0.088g, 0.012g maleic acid anhydride-propenoic acid methyl terpolymer in
In reaction kettle, the oil field injection water of 100mL is added in into reaction kettle and being heated to 50 DEG C of stirrings is sufficiently uniformly dissolved it, system
It is standby to obtain above-mentioned increasing injection surfactant compound composition.
The present embodiment additionally provides the application of above-mentioned increasing injection surfactant compound composition, specifically can be according to
Following steps carry out：
Continue supplement into above-mentioned increasing injection surfactant compound composition and add in 400mL oil fields injection water,
The surfactant compound composition solution that solute percent of total content is 0.05wt% is configured to, uses it for under-injected well decompression
When the effective connected oil wells moisture content of water filling well group is 50%, the surfactant compound of 0.1PV is continuously injected into well for augmented injection
The solution of composition.
Embodiment 2
The present embodiment provides a kind of increasing injection surfactant compound compositions, in parts by weight, raw material components bag
It includes：
Dodecanamide propyl hydroxy sulfo lycine：0.05 part；
Epicholorohydrin-dimethylamine Cationic Polymer：0.14 part of (wherein, molar ratio of epoxychloropropane and dimethylamine
For 1.5:1)；
Maleic acid anhydride-propenoic acid methacrylate copolymers：0.01 part (wherein, the molar ratio of maleic anhydride and ethyl acrylate is
3:2)；
Oil field injection water：100 parts.
The increasing injection surfactant compound composition of the present embodiment is prepared via a method which to obtain：
In atmospheric conditions, according to raw material components parts by weight meter, the dodecanamide propyl hydroxyl sulfobetaines of 0.05g are weighed
Alkali, the Epicholorohydrin-dimethylamine Cationic Polymer of 0.14g, the maleic acid anhydride-propenoic acid methacrylate copolymers of 0.01g are in anti-
It answers in kettle, the oil field injection water of 100mL is added in into reaction kettle and being heated to 55 DEG C of stirrings is sufficiently uniformly dissolved it, is prepared
Obtain above-mentioned increasing injection surfactant compound composition.
The present embodiment additionally provides the application of above-mentioned increasing injection surfactant compound composition, specifically can be according to
Following steps carry out：
Continue supplement into above-mentioned increasing injection surfactant compound composition and add in 100mL oil fields injection water,
The surfactant compound composition solution that solute percent of total content is 0.1wt% is configured to, uses it for under-injected well decompression
Augmented injection, when the effective connected oil wells moisture content of water filling well group is 60%, the surfactant that 0.15PV is continuously injected into well is answered
Solution with composition.
Embodiment 3
The present embodiment provides a kind of increasing injection surfactant compound compositions, in parts by weight, raw material components bag
It includes：
Myristyl amide hydroxysultaine：0.2 part；
Epicholorohydrin-dimethylamine Cationic Polymer：0.05 part of (wherein, molar ratio of epoxychloropropane and dimethylamine
For 1.5:1)；
Maleic acid anhydride-propenoic acid methyl terpolymer：0.005 part (wherein, the molar ratio of maleic anhydride and methyl acrylate is
3:2)；
Oil field injection water：100 parts.
The increasing injection surfactant compound composition of the present embodiment is prepared via a method which to obtain：
In atmospheric conditions, according to raw material components parts by weight meter, the myristyl amide propyl hydroxyl sulfo group sweet tea of 0.2g is weighed
Dish alkali, the Epicholorohydrin-dimethylamine Cationic Polymer of 0.05g, 0.005g maleic acid anhydride-propenoic acid methyl terpolymer in
In reaction kettle, the oil field injection water of 100mL is added in into reaction kettle and being heated to 60 DEG C of stirrings is sufficiently uniformly dissolved it, system
It is standby to obtain above-mentioned increasing injection surfactant compound composition.
The present embodiment additionally provides the application of above-mentioned increasing injection surfactant compound composition, specifically can be according to
Following steps carry out：
Continue supplement into above-mentioned increasing injection surfactant compound composition and add in 70mL oil fields injection water, match somebody with somebody
The surfactant compound composition solution that solute percent of total content is 0.15wt% is made, uses it for under-injected well decompression and increases
When the effective connected oil wells moisture content of water filling well group is 65%, the surfactant compound group of 0.2PV is continuously injected into well for note
Close the solution of object.
Embodiment 4
The present embodiment provides a kind of increasing injection surfactant compound compositions, in parts by weight, raw material components bag
It includes：
Octadecyl amide hydroxysultaine：0.1 part；
Epicholorohydrin-dimethylamine Cationic Polymer：0.15 part of (wherein, molar ratio of epoxychloropropane and dimethylamine
For 1.5:1)；
Maleic acid anhydride-propenoic acid acrylate copolymer：0.01 part (wherein, the molar ratio of maleic anhydride and butyl acrylate is
3:2)；
Oil field injection water：100 parts.
The increasing injection surfactant compound composition of the present embodiment is prepared via a method which to obtain：
In atmospheric conditions, according to raw material components parts by weight meter, the octadecyl amide propyl hydroxyl sulfo group sweet tea of 0.1g is weighed
Dish alkali, the Epicholorohydrin-dimethylamine Cationic Polymer of 0.15g, 0.01g maleic acid anhydride-propenoic acid acrylate copolymer in
In reaction kettle, the oil field injection water of 100mL is added in into reaction kettle and being heated to 70 DEG C of stirrings is sufficiently uniformly dissolved it, system
It is standby to obtain above-mentioned increasing injection surfactant compound composition.
The present embodiment additionally provides the application of above-mentioned increasing injection surfactant compound composition, specifically can be according to
Following steps carry out：
Continue supplement into above-mentioned increasing injection surfactant compound composition and add in 30mL oil fields injection water, match somebody with somebody
The surfactant compound composition solution that solute percent of total content is 0.2wt% is made, uses it for under-injected well decompression and increases
When the effective connected oil wells moisture content of water filling well group is 70%, the surfactant compound group of 0.3PV is continuously injected into well for note
Close the solution of object.
Embodiment 5
Embodiment 1 is prepared to obtained increasing injection surfactant compound composition and is configured to different solute percent of totals
The increasing injection surfactant compound composition solution of content, is determined as follows its property.
(1) measure of the reduction oil water interfacial tension ability of increasing injection surfactant compound composition
The increasing injection surfactant compound composition of Example 1, being configured to solute percent of total content is respectively
The surfactant compound composition solution of 0.05wt%, 0.1wt%, 0.2wt%.It is surveyed using TX-500C types interfacial tensimeter
Fixed above-mentioned complex composition reduces the ability of oil water interfacial tension.Experiment oil is the simulation oil of dewatered oil preparation (at 77 DEG C
Viscosity be 5cp).
Measurement result is as shown in Figure 1, the results showed that：The increasing injection surfactant compound composition can make grease
Equilibrium interfacial tension can drop to 10-1The mN/m orders of magnitude, Transient interfacial tension can be reduced to 10-2The mN/m orders of magnitude, it is so existing
Beneficial to the startup of residual oil, while largely emulsification can be caused to crude oil to avoid complex composition again and cause water injection pressure liter
Height reduces capillary force, weakens liquid lock effect.
(2) measure for preventing swollen ability of increasing injection surfactant compound composition
According to standard SY/T 5971-94 (water filling clay stabilizer method of evaluating performance), surface work is determined respectively
Property agent complex composition is to the preventive effect of expansion of montmorillonite and rock core powder.Rock core powder grinds for live institute coring, in experiment
Oil used is kerosene, and water is scene injection water.Expansion rate calculation formula is as follows：
In formula：
B1--- anti-dilative, %；
V1--- swelling volume of the montmorillonite in clay stabilization agent solution, mL；
V2--- montmorillonite swelling volume in water, mL；
V0--- volume of the montmorillonite in kerosene, mL.
The increasing injection surfactant compound composition of Example 1, being configured to solute percent of total content is respectively
The surfactant compound composition solution of 0.05wt%, 0.1wt%, 0.15wt%, 0.2wt% carry out the measure of anti-dilative,
The results are shown in Figure 2, measures anti-dilative and has respectively reached 31.82%, 48.93%, 55.44%, 60.10%.Above-mentioned detection knot
Fruit shows：With the increase of the percent of total content of the solute in surfactant compound composition solution, anti-dilative is higher, prevents
Swollen effect is better, this illustrates that the increasing injection surfactant compound composition has good anti-swollen ability.
(3) measure of the antiscale ability of increasing injection surfactant compound composition
According to standard SY/T 5673-93 (scale inhibitor for oilfield Reliable Evaluating Methods of Their Performance), the anti-scaling property of composition is carried out
It measures.Nitrogen, the CO being precipitated in stripping water are constantly blasted during experiment into equivalent water sample2, the pH value in water is made to reach nature
Balance keeps water sample constant temperature (53 DEG C of formation temperature) in experiment, after experiment, the hardness of water sample becomes before and after assay experiment
Change, calculate scale inhibition performance.Evaluation method is：
In formula：
η --- scale inhibition performance, %；
S1--- the water sample total hardness of medicament, mg/L are added in after experiment；
S2--- the water sample total hardness of medicament, mg/L are not added in after experiment；
S0--- originally water sample total hardness, mg/L.
The increasing injection surfactant compound composition of Example 1, being configured to solute percent of total content is respectively
The surfactant compound composition solution of 0.05wt%, 0.1wt%, 0.2wt% carry out the measure of antiscaling rate, as a result such as Fig. 3
It is shown, it measures rock core antiscaling rate and has respectively reached 34.69%, 66.53% and 77.14%.Above-mentioned testing result shows：With table
The increase of the percent of total content of solute in the activating agent complex composition solution of face, scale inhibition performance is higher, and scale inhibition effect is better, says
The bright increasing injection surfactant compound composition can play good anti-scaling action.
(4) measure of the improvement two-phase flow ability of increasing injection surfactant compound composition
Rock core vacuumizing after washing oil is dried, saturation simulation water flooding, saturated oils.It injects water and carries out flood pot test,
Record is lower at different moments to produce water, oil production and corresponding displacement pressure difference, records the anhydrous period oil production before water breakthrough, accurate recording
Water breakthrough time, rock sample both ends pressure difference.Water breakthrough initial stage, scrambled record, according to how much selection time intervals of oil pump capacity, with oil pump capacity
It is continuous decline the time interval for gradually lengthening record, until water drive oil reaches residual oil state.Calculation of water gas relative permeability
With corresponding water saturation and moisture content, and relative permeability and water saturation curve are drawn.
The increasing injection surfactant compound composition of Example 1, being configured to solute percent of total content is
The surfactant compound composition solution of 0.1wt%, the surfactant compound composition that injection water is changed into 0.1wt% are molten
Liquid repeats above-mentioned oil displacement experiment.
Measurement result is as shown in Figure 4, the results showed that：After the displacement of reservoir oil being carried out using surfactant compound composition solution, oil
It all increases with the relative permeability of water, especially oily relative permeability improves more apparent.Phase percolation curve during water drive oil
The corresponding water saturation of isotonic point be less than 50%, illustrate core surface be in slightly oil-wet state.Utilize complex composition solution
After carrying out the displacement of reservoir oil, the corresponding water saturation of isotonic point is shifted to the right to more than 50%, illustrates that core surface physicochemical properties occur
Hydrophily is presented in variation, core surface.
The surfactant compound composition can be such that oil-wet core changes to hydrophilic direction, improve water phase permeability, oil
Water two-phase permeation scope broadens, and fettering oily saturation degree reduces, and improves recovery ratio.
(5) measure of the decompression ability of increasing injection surfactant compound composition
The increasing injection surfactant compound composition of Example 1, being configured to solute percent of total content is
The surfactant compound composition solution of 0.1wt%.
Simulated formation water is injected into rock core with the speed of 0.05mL/min, after pressure stability, with identical speed to
The surfactant compound composition solution that solute percent of total content is 0.1wt% is injected in rock core, is recorded in injection process
Pressure change.
Measurement result is as shown in Figure 5, the results showed that：As injected slurry volume increases, injection pressure declines.When injection compounding group
After polymer solution, barometric gradient stabilization reduces 16.44% in 0.798MPa/cm, pressure, and it is good that this illustrates that said composition has
Drop low injection pressure ability.
(6) the increasing injection surfactant compound composition displacement test of different solute percent of total contents
The increasing injection surfactant compound composition of Example 1, being configured to solute percent of total content is respectively
The surfactant compound composition solution of 0.05wt%, 0.2wt%, 0.3wt% carry out displacement test, as a result such as Fig. 6 to 8
Shown in table 1.
It can be seen from Fig. 6 to 8 the increasing injection surfactant compound composition of different solute percent of total contents into
During the row displacement of reservoir oil, there are one the stages first risen for barometric gradient.Wherein, when the increasing injection surfactant using 0.3wt%
When complex composition carries out the displacement of reservoir oil, peak is rapidly risen in initial period barometric gradient, then starts slowly to decline, finally
It tends to balance.This is mainly due to oil water interfacial tension at this time, ultralow (lowest interfacial tension reaches 10-3The mN/m orders of magnitude, balance
Interfacial tension reaches 10-2The mN/m orders of magnitude), it is easily acted on crude oil and generates emulsification, emulsify the droplet of formation in tiny pore throat
Place blocks, flow resistance increase, causes injection barometric gradient rise；As residual oil is further washed out, emulsification
Reduce, flow resistance reduces, and barometric gradient is just begun to decline, last curve held stationary.
Table 1 carries out the displacement of reservoir oil and water drive for the increasing injection surfactant compound composition of different solute percent of total contents
Pressure comparison result after oil experiment.
Table 1
Using the increasing injection surfactant compound composition of different solute degrees, different interfaces represent
Tension, when equilibrium interfacial tension is 10 it can be seen from 1 result of table-1MN/m to 10-2Between the mN/m orders of magnitude, lived using surface
Property agent complex composition carry out the displacement of reservoir oil increasing injection effect it is preferable, when interfacial tension continues to reduce, be close to or up to 10-3mN/m
When, due to generating substantial amounts of emulsification, water injection pressure is caused to reduce amplitude, and there is no increase.It is carried out in view of surfactant
The financial cost of the displacement of reservoir oil is higher, so the interfacial tension when displacement of reservoir oil is carried out using surfactant compound system is 10-1MN/m is arrived
10-2Between the mN/m orders of magnitude, increasing injection effect can be more preferable.
In conclusion the increasing injection surfactant compound composition can be effectively reduced injection pressure,
Oil water interfacial tension is reduced, not only improves the startup of residual oil, and can be to avoid complex composition causes to emulsify to crude oil and draws
Water injection pressure rise is played, improves under-injected well water injection capacity, while can also prevent clay swell, inhibit the carbonate depositions such as calcium carbonate
Injury to stratum.The increasing injection surfactant compound composition can also be such that oil-wet core changes to hydrophilic direction, carry
High water phase permeability, water-oil phase permeation scope broaden, and fettering oily saturation degree reduces, and improves recovery ratio.
Claims (7)
1. a kind of increasing injection surfactant compound composition, in parts by weight, raw material components include amophoteric surface active
0.05-0.2 parts of agent, 0.05-0.15 parts of clay stabilizer, 0.005-0.012 parts of scale preventative, 100 parts of water；
The amphoteric surfactant is betaine type amphoteric surfac-tant；The clay stabilizer polymerize for organic cation
Object；The scale preventative is water soluble polymeric scale preventative；The water injects water for oil field；
The betaine type amphoteric surfac-tant is the hydroxy sulfo lycine containing amide groups, and structural formula is as follows：
Wherein, R3For the C substituted containing amide groups15-C28Long chain hydrocarbon groups, R1And R2It is C1-C3Short-chain hydrocarbon group；
The organic cationic polymer is quaternary organic cationic polymer；The quaternary organic cation polymerization
Object is Epicholorohydrin-dimethylamine Cationic Polymer, in the Epicholorohydrin-dimethylamine Cationic Polymer, epoxy chloropropionate
The molar ratio of alkane and dimethylamine is 1.5:1；
The water soluble polymeric scale preventative includes maleic-acrylic acid type copolymer and/or maleic acid anhydride-propenoic acid type is total to
Polymers；The maleic-acrylic acid type copolymer and/or maleic acid anhydride-propenoic acid type copolymer include maleic acid anhydride-propenoic acid
One or more in methyl terpolymer, maleic acid anhydride-propenoic acid methacrylate copolymers, maleic acid anhydride-propenoic acid acrylate copolymer
Combination；In the maleic acid anhydride-propenoic acid methyl terpolymer, the molar ratio of maleic anhydride and methyl acrylate is 3:2, it is described
In maleic acid anhydride-propenoic acid methacrylate copolymers, the molar ratio of maleic anhydride and ethyl acrylate is 3:2, the maleic anhydride-the third
In olefin(e) acid acrylate copolymer, the molar ratio of maleic anhydride and butyl acrylate is 3:2.
2. surfactant compound composition according to claim 1, which is characterized in that the hydroxyl sulphur containing amide groups
Base glycine betaine includes octadecyl amide hydroxysultaine.
3. the preparation method of the increasing injection surfactant compound composition described in claim 1 or 2, comprises the following steps：
(1) in atmospheric conditions, amphoteric surfactant, clay stabilizer, scale preventative are taken in reaction kettle；
(2) water is added in into reaction kettle and is heated to 50 DEG C -70 DEG C, stirring is sufficiently uniformly dissolved it, and the decompression is prepared
Augmented injection surfactant compound composition.
4. the increasing injection surfactant compound composition described in claim 1 or 2 is as injection water additive in under-injected well
On application, include the following steps：
When the effective connected oil wells moisture content of water filling well group is 50%-70%, the surface that more than 0.1PV is continuously injected into well is lived
The solution of property agent complex composition is steady with amphoteric surfactant, clay in the solution of the surfactant compound composition
Agent and scale preventative are determined as solute, and the percent of total content of solute is 0.05wt%-0.2wt%.
5. application according to claim 4, which is characterized in that the injection of the solution of the surfactant compound composition
It measures as 0.1-0.3PV.
6. application according to claim 4, which is characterized in that when oil pressure or pump pressure are within formation fracture pressure 1MPa
When, in the solution of surfactant compound composition, the percent of total content of solute is 0.05wt%-0.1wt%；
When oil pressure or pump pressure are more than or equal to 1MPa apart from formation fracture pressure, in the solution of surfactant compound composition
In, the percent of total content of solute is 0.1wt%-0.2wt%.
7. application according to claim 4, which is characterized in that the surfactant compound composition is for permeability
Special low, extra-low-permeability reservoir less than 5mD.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201510622029.8A CN105154051B (en) | 2015-09-25 | 2015-09-25 | Pressure-reducing injection-increasing surfactant compound composition and preparation method and application thereof |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201510622029.8A CN105154051B (en) | 2015-09-25 | 2015-09-25 | Pressure-reducing injection-increasing surfactant compound composition and preparation method and application thereof |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN105154051A CN105154051A (en) | 2015-12-16 |
| CN105154051B true CN105154051B (en) | 2018-06-01 |
Family
ID=54795111
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201510622029.8A Active CN105154051B (en) | 2015-09-25 | 2015-09-25 | Pressure-reducing injection-increasing surfactant compound composition and preparation method and application thereof |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN105154051B (en) |
Families Citing this family (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| FR3056217B1 (en) * | 2016-09-21 | 2020-06-19 | S.P.C.M. Sa | PROCESS FOR OBTAINING CATIONIC POLYMERS WITH REDUCED HALIDE CONTENT |
| CN108504344B (en) * | 2017-02-28 | 2020-09-22 | 中国石油化工股份有限公司 | High-temperature-resistant high-salinity activator capable of reducing starting pressure gradient of ultra-low-permeability reservoir |
| CN109913193B (en) * | 2017-12-13 | 2021-03-30 | 中国石油天然气股份有限公司 | Pressure-reducing and injection-increasing agent for water injection well of low-permeability oil reservoir and preparation method thereof |
| CN108559473B (en) * | 2018-05-15 | 2021-02-19 | 大庆华理生物技术有限公司 | Biological surfactant-containing water injection well pressure-reducing and injection-increasing agent |
| CN112980420B (en) * | 2019-12-12 | 2023-06-09 | 中国石油化工股份有限公司 | Antihypertensive injection and preparation method thereof |
| CN113136187A (en) * | 2021-03-24 | 2021-07-20 | 中国地质大学（武汉） | Neutral gradient water injection particle migration anti-blocking system and preparation method thereof |
| CN115386358B (en) * | 2022-06-30 | 2023-08-08 | 常州大学 | Natural surfactant compound system and preparation method thereof |
Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101812290A (en) * | 2010-05-11 | 2010-08-25 | 陕西科技大学 | Acid clean fracturing fluid and preparation method thereof |
| CN103897684A (en) * | 2014-03-20 | 2014-07-02 | 陕西省石油化工研究设计院 | Preparation method and application of unified clean fracturing fluid |
| CN104295275A (en) * | 2013-07-17 | 2015-01-21 | 中国石油化工股份有限公司 | Deep blockage removal and injection increase method for water injection well of medium-and-high-permeability sandstone reservoir |
-
2015
- 2015-09-25 CN CN201510622029.8A patent/CN105154051B/en active Active
Patent Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101812290A (en) * | 2010-05-11 | 2010-08-25 | 陕西科技大学 | Acid clean fracturing fluid and preparation method thereof |
| CN104295275A (en) * | 2013-07-17 | 2015-01-21 | 中国石油化工股份有限公司 | Deep blockage removal and injection increase method for water injection well of medium-and-high-permeability sandstone reservoir |
| CN103897684A (en) * | 2014-03-20 | 2014-07-02 | 陕西省石油化工研究设计院 | Preparation method and application of unified clean fracturing fluid |
Also Published As
| Publication number | Publication date |
|---|---|
| CN105154051A (en) | 2015-12-16 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN105154051B (en) | Pressure-reducing injection-increasing surfactant compound composition and preparation method and application thereof | |
| US8188012B2 (en) | Process of using hard brine at high alkalinity for enhanced oil recovery (EOR) applications | |
| US3275075A (en) | Viscosity control in petroleum recovery | |
| RU2710269C2 (en) | Foam removal of liquid with application of ether sulfonates of alcohols | |
| US5095989A (en) | Microemulsion method for improving the injectivity of a well | |
| CN113646381B (en) | Reverse emulsion for hydraulic fracturing | |
| CN101528888A (en) | Functional polymer for enhanced oil recovery | |
| CN102939354A (en) | Surfactant-less alkaline-polymer formulations for recovering reactive crude oil | |
| US20150141303A1 (en) | Binary and ternary surfactant blends for enhanced oil recovery in reservoir brines with extremely high total dissolved solids | |
| CN113462373B (en) | Low-permeability oil and gas reservoir waterproof locking agent and preparation method and application thereof | |
| CN104498014A (en) | Gel breaking liquid based modifying and flooding agent and preparation method thereof | |
| US4582138A (en) | Method for oil recovery from reservoir rock formations | |
| CN112724949B (en) | Lactic acidlike blocking remover for blocking removal of thick oil well and application thereof | |
| CN114752366A (en) | Biological surfactant plugging-removing injection-increasing agent and application system | |
| CN106967406A (en) | A kind of oil displacement system and flooding method for heterogeneous reservoir | |
| CN105860949A (en) | Imbibition agent composition and preparation thereof | |
| CN103146371A (en) | Molecular film drag-reduction injection-stimulation agent for low permeability sandstone reservoir | |
| CN114854382B (en) | Low-permeability oil reservoir bio-based microemulsion blocking removal and injection enhancement system and injection process thereof | |
| CA1179114A (en) | Method for recovering oil from a subterranean deposit | |
| CN103923632A (en) | Desorbent and its evaluation method | |
| CA1199783A (en) | Method for recovering oil from an underground deposit | |
| WO2014055342A1 (en) | Traceable polymeric viscosifier compositions and methods of using | |
| CN115322763B (en) | Biological acidolysis blocking agent, preparation method thereof and application thereof in low-permeability reservoir | |
| CN109652029A (en) | A kind of sea water base drilling fluid salt-resisting high-temperature-resisting fluid loss additive and preparation method thereof | |
| US3605892A (en) | Imparting in situ stability to displacing fluids |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |