CN116987494A - Microemulsion imbibition oil extraction agent and preparation method and application method thereof - Google Patents
Microemulsion imbibition oil extraction agent and preparation method and application method thereof Download PDFInfo
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- 239000004530 micro-emulsion Substances 0.000 title claims abstract description 61
- 238000005213 imbibition Methods 0.000 title claims abstract description 47
- 239000003795 chemical substances by application Substances 0.000 title claims abstract description 45
- 238000000605 extraction Methods 0.000 title claims abstract description 32
- 238000000034 method Methods 0.000 title claims description 16
- 238000002360 preparation method Methods 0.000 title abstract description 17
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims abstract description 40
- KWIUHFFTVRNATP-UHFFFAOYSA-N Betaine Natural products C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 claims abstract description 33
- 238000011084 recovery Methods 0.000 claims abstract description 31
- 239000011780 sodium chloride Substances 0.000 claims abstract description 31
- -1 modified sophorolipid sulfonate Chemical class 0.000 claims abstract description 27
- 229960003237 betaine Drugs 0.000 claims abstract description 17
- 239000004064 cosurfactant Substances 0.000 claims abstract description 11
- 125000000217 alkyl group Chemical group 0.000 claims abstract description 10
- TYRGSDXYMNTMML-UHFFFAOYSA-N propyl hydrogen sulfate Chemical compound CCCOS(O)(=O)=O TYRGSDXYMNTMML-UHFFFAOYSA-N 0.000 claims abstract description 6
- 150000001408 amides Chemical class 0.000 claims abstract description 4
- 239000003921 oil Substances 0.000 claims description 118
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 54
- ZTOKUMPYMPKCFX-CZNUEWPDSA-N (E)-17-[(2R,3R,4S,5S,6R)-6-(acetyloxymethyl)-3-[(2S,3R,4S,5S,6R)-6-(acetyloxymethyl)-3,4,5-trihydroxyoxan-2-yl]oxy-4,5-dihydroxyoxan-2-yl]oxyoctadec-9-enoic acid Chemical class OC(=O)CCCCCCC/C=C/CCCCCCC(C)O[C@@H]1O[C@H](COC(C)=O)[C@@H](O)[C@H](O)[C@H]1O[C@H]1[C@H](O)[C@@H](O)[C@H](O)[C@@H](COC(C)=O)O1 ZTOKUMPYMPKCFX-CZNUEWPDSA-N 0.000 claims description 23
- BDERNNFJNOPAEC-UHFFFAOYSA-N propan-1-ol Chemical compound CCCO BDERNNFJNOPAEC-UHFFFAOYSA-N 0.000 claims description 22
- 239000000243 solution Substances 0.000 claims description 19
- 239000002904 solvent Substances 0.000 claims description 15
- 239000008399 tap water Substances 0.000 claims description 12
- 235000020679 tap water Nutrition 0.000 claims description 12
- 238000002156 mixing Methods 0.000 claims description 11
- 238000003756 stirring Methods 0.000 claims description 9
- 239000010779 crude oil Substances 0.000 claims description 8
- LRHPLDYGYMQRHN-UHFFFAOYSA-N N-Butanol Chemical compound CCCCO LRHPLDYGYMQRHN-UHFFFAOYSA-N 0.000 claims description 6
- 150000003839 salts Chemical class 0.000 claims description 6
- 230000007935 neutral effect Effects 0.000 claims description 5
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 claims description 4
- 125000004432 carbon atom Chemical group C* 0.000 claims description 4
- ZXEKIIBDNHEJCQ-UHFFFAOYSA-N isobutanol Chemical compound CC(C)CO ZXEKIIBDNHEJCQ-UHFFFAOYSA-N 0.000 claims description 4
- 239000003129 oil well Substances 0.000 claims description 4
- QAOWNCQODCNURD-UHFFFAOYSA-N Sulfuric acid Chemical compound OS(O)(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-N 0.000 claims description 3
- 230000033558 biomineral tissue development Effects 0.000 claims description 3
- 239000012267 brine Substances 0.000 claims description 3
- 238000004519 manufacturing process Methods 0.000 claims description 3
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims description 3
- 125000003158 alcohol group Chemical group 0.000 claims description 2
- 150000001335 aliphatic alkanes Chemical class 0.000 claims description 2
- 239000003513 alkali Substances 0.000 claims description 2
- 125000003342 alkenyl group Chemical group 0.000 claims description 2
- 150000001768 cations Chemical class 0.000 claims description 2
- 239000003350 kerosene Substances 0.000 claims description 2
- 230000008901 benefit Effects 0.000 abstract description 8
- 238000006243 chemical reaction Methods 0.000 abstract description 3
- 230000007613 environmental effect Effects 0.000 abstract description 3
- 239000013043 chemical agent Substances 0.000 abstract description 2
- 238000009776 industrial production Methods 0.000 abstract description 2
- KWIUHFFTVRNATP-UHFFFAOYSA-O N,N,N-trimethylglycinium Chemical compound C[N+](C)(C)CC(O)=O KWIUHFFTVRNATP-UHFFFAOYSA-O 0.000 abstract 1
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 30
- 239000000203 mixture Substances 0.000 description 21
- 238000010521 absorption reaction Methods 0.000 description 13
- 102100033925 GS homeobox 1 Human genes 0.000 description 11
- 101001068303 Homo sapiens GS homeobox 1 Proteins 0.000 description 11
- 238000006073 displacement reaction Methods 0.000 description 8
- 239000012530 fluid Substances 0.000 description 8
- 238000011161 development Methods 0.000 description 7
- 230000018109 developmental process Effects 0.000 description 7
- 239000011435 rock Substances 0.000 description 7
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 6
- 230000000694 effects Effects 0.000 description 6
- 238000002347 injection Methods 0.000 description 6
- 239000007924 injection Substances 0.000 description 6
- 230000035699 permeability Effects 0.000 description 5
- 239000004094 surface-active agent Substances 0.000 description 5
- 238000012360 testing method Methods 0.000 description 5
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 description 4
- 239000007789 gas Substances 0.000 description 4
- 150000002596 lactones Chemical class 0.000 description 4
- 239000011148 porous material Substances 0.000 description 4
- 230000008569 process Effects 0.000 description 4
- 229940117986 sulfobetaine Drugs 0.000 description 4
- ZMXDDKWLCZADIW-UHFFFAOYSA-N N,N-Dimethylformamide Chemical compound CN(C)C=O ZMXDDKWLCZADIW-UHFFFAOYSA-N 0.000 description 3
- 239000003153 chemical reaction reagent Substances 0.000 description 3
- 230000000052 comparative effect Effects 0.000 description 3
- 239000000306 component Substances 0.000 description 3
- 239000011258 core-shell material Substances 0.000 description 3
- 150000002191 fatty alcohols Chemical class 0.000 description 3
- 239000008398 formation water Substances 0.000 description 3
- 229920000642 polymer Polymers 0.000 description 3
- 229920006395 saturated elastomer Polymers 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- PSBDWGZCVUAZQS-UHFFFAOYSA-N (dimethylsulfonio)acetate Chemical compound C[S+](C)CC([O-])=O PSBDWGZCVUAZQS-UHFFFAOYSA-N 0.000 description 2
- UIIMBOGNXHQVGW-UHFFFAOYSA-M Sodium bicarbonate Chemical compound [Na+].OC([O-])=O UIIMBOGNXHQVGW-UHFFFAOYSA-M 0.000 description 2
- ILRSCQWREDREME-UHFFFAOYSA-N dodecanamide Chemical compound CCCCCCCCCCCC(N)=O ILRSCQWREDREME-UHFFFAOYSA-N 0.000 description 2
- 239000003995 emulsifying agent Substances 0.000 description 2
- 238000000855 fermentation Methods 0.000 description 2
- 230000004151 fermentation Effects 0.000 description 2
- 239000011159 matrix material Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 230000000813 microbial effect Effects 0.000 description 2
- 239000007908 nanoemulsion Substances 0.000 description 2
- 239000002736 nonionic surfactant Substances 0.000 description 2
- 125000005010 perfluoroalkyl group Chemical group 0.000 description 2
- 229940051841 polyoxyethylene ether Drugs 0.000 description 2
- 229920000056 polyoxyethylene ether Polymers 0.000 description 2
- 239000001103 potassium chloride Substances 0.000 description 2
- 235000011164 potassium chloride Nutrition 0.000 description 2
- 239000002994 raw material Substances 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 239000011734 sodium Substances 0.000 description 2
- 238000006277 sulfonation reaction Methods 0.000 description 2
- AKEJUJNQAAGONA-UHFFFAOYSA-N sulfur trioxide Chemical compound O=S(=O)=O AKEJUJNQAAGONA-UHFFFAOYSA-N 0.000 description 2
- 239000002888 zwitterionic surfactant Substances 0.000 description 2
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 1
- HVUMOYIDDBPOLL-XWVZOOPGSA-N Sorbitan monostearate Chemical compound CCCCCCCCCCCCCCCCCC(=O)OC[C@@H](O)[C@H]1OC[C@H](O)[C@H]1O HVUMOYIDDBPOLL-XWVZOOPGSA-N 0.000 description 1
- 239000002250 absorbent Substances 0.000 description 1
- 230000002745 absorbent Effects 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 239000013543 active substance Substances 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 230000000996 additive effect Effects 0.000 description 1
- 230000032683 aging Effects 0.000 description 1
- 125000000129 anionic group Chemical group 0.000 description 1
- 239000003945 anionic surfactant Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000001110 calcium chloride Substances 0.000 description 1
- 229910001628 calcium chloride Inorganic materials 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 239000008139 complexing agent Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000004090 dissolution Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000011049 filling Methods 0.000 description 1
- 239000013505 freshwater Substances 0.000 description 1
- 231100000171 higher toxicity Toxicity 0.000 description 1
- 230000015784 hyperosmotic salinity response Effects 0.000 description 1
- 229910017053 inorganic salt Inorganic materials 0.000 description 1
- 230000007794 irritation Effects 0.000 description 1
- 231100000053 low toxicity Toxicity 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 239000005426 pharmaceutical component Substances 0.000 description 1
- ONJQDTZCDSESIW-UHFFFAOYSA-N polidocanol Chemical compound CCCCCCCCCCCCOCCOCCOCCOCCOCCOCCOCCOCCOCCO ONJQDTZCDSESIW-UHFFFAOYSA-N 0.000 description 1
- 235000010482 polyoxyethylene sorbitan monooleate Nutrition 0.000 description 1
- 229920000053 polysorbate 80 Polymers 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 238000009738 saturating Methods 0.000 description 1
- 235000017557 sodium bicarbonate Nutrition 0.000 description 1
- 229910000030 sodium bicarbonate Inorganic materials 0.000 description 1
- 238000005063 solubilization Methods 0.000 description 1
- 230000007928 solubilization Effects 0.000 description 1
- 230000003381 solubilizing effect Effects 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- UDYFLDICVHJSOY-UHFFFAOYSA-N sulfur trioxide-pyridine complex Substances O=S(=O)=O.C1=CC=NC=C1 UDYFLDICVHJSOY-UHFFFAOYSA-N 0.000 description 1
- 238000005406 washing 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
-
- 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
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Organic Chemistry (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Materials Engineering (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Geochemistry & Mineralogy (AREA)
- Colloid Chemistry (AREA)
Abstract
The application provides a biodegradable microemulsion imbibition oil extraction agent, which comprises the following components: 15-35 parts of alkyl amide propyl hydroxysulfonic acid betaine; (2) 4-20 parts of modified sophorolipid sulfonate; (3) 5-18 parts of cosurfactant; (4) 3-25 parts of an oil component; 30-70 parts of saline. The microemulsion imbibition oil extraction agent can improve imbibition recovery ratio of low-permeability or dense oil reservoirs, and has the advantages of simple preparation process, mild reaction condition and high yield, and is particularly suitable for industrial production, and has remarkable economic benefit. The used chemical agent is green and environment-friendly, can be biodegraded, and can bring better environmental benefit.
Description
Technical Field
The application relates to an oilfield oil extraction agent, in particular to a biodegradable oil extraction agent.
Background
Oil and natural gas have become one of three strategic resources that affect the economic construction and sustainable development of our country. The exploitation technology for improving the hypotonic oil reservoir and the compact oil gas resource breaks through the development theoretical research and the technical bottleneck of the oil gas resource, and has very important practical significance. The low permeability oil reservoir has low permeability and poor pore connectivity, the injection pressure is high in the water injection development process, the fluid mainly flows through cracks, the fluid in matrix rock is difficult to flow, a large amount of injected water directly flows into a production well through the cracks, the oil displacement effect is not achieved, the ineffective circulation water injection is achieved, and the development effect is poor.
Imbibition oil extraction is an important development method for low-permeability or dense oil reservoirs, utilizes capillary force to absorb water and discharge oil, strengthens oil-water displacement capability between a matrix and cracks, and effectively improves crude oil recovery efficiency.
The microemulsion is an optically isotropic and thermodynamically stable solution system composed of oil, water and amphiphilic substances (molecules), and is transparent or semitransparent in appearance, and has good solubilization effect and ultralow interfacial tension. Research shows that the imbibition test is carried out in fresh water, saline water and microemulsion, and the imbibition speed in the microemulsion is found to be the fastest, and the extraction rate is the highest. In low pore, hypotonic reservoirs, microemulsions can greatly promote water penetration, and transport to the interface for action faster than surfactants. The diameter of the microemulsion seepage and absorption agent is mainly distributed at about 10nm-200nm, and the microemulsion seepage and absorption agent can enter into micro-pore channels of a low-permeability oil reservoir due to the unique physical and chemical properties, so that the effects of reducing the oil-water interfacial tension, reducing the injection pressure and solubilizing the residual oil are achieved, and the recovery ratio is improved. The surfactant in the microemulsion is adsorbed on the rock wall surface, so that the wettability of the rock is changed, and the imbibition efficiency is improved. The microemulsion can form a mixed phase with stratum oil, and the recovery ratio is improved. In addition, oil-in-water microemulsions solubilize large amounts of oil, which is pumped downhole with the microemulsion. When the surfactant forming the microemulsion is anionic, the surfactant is adsorbed on the surfaces of the oil droplets and the stratum, so that the charge density of the rock surface can be improved, and the electrostatic repulsive force of the oil droplets and the stratum surface can be increased. When the subsequent displacement fluid passes through the oil droplets, the oil droplets are easy to be taken away, and the oil washing efficiency is improved. In the underground flowing process, the microemulsion can automatically improve the microscopic heterogeneity of the oil reservoir, increase the viscosity of the displacement fluid, improve the oil-water fluidity ratio, promote the solution to actively enter the low-permeability reservoir, and achieve the effect similar to profile control, thereby improving the sweep efficiency.
Patent CN 113004882A discloses a microemulsion type seepage and absorption agent, a preparation method thereof and an oil displacement type fracturing fluid system, wherein the microemulsion type seepage and absorption agent has a 'core-shell' structure, the diameter of the microemulsion type seepage and absorption agent is 9nm-500nm, and the microemulsion type seepage and absorption agent comprises 20-35% of solvent, 15-25% of emulsifying agent, 1-2.5% of complexing agent and the balance of water in percentage by weight; the emulsifier comprises, by weight, 35-60% of fatty alcohol ether grafted comb polymer, 25-35% of zwitterionic surfactant, 2-5% of perfluoroalkyl polyoxyethylene ether and the balance of water. The perfluoroalkyl polyoxyethylene ether interacts with the fatty alcohol ether grafted comb polymer active agent and the zwitterionic surfactant to form a whole, namely a shell with a 'core-shell structure', so that the surface tension is effectively reduced. The fracturing fluid system containing the microemulsion type permeation absorbent with the 'core-shell structure' has strong displacement capability and higher displacement efficiency compared with the conventional oil displacement agent. However, the fatty alcohol ether grafted comb polymer used in the application has larger molecular weight, is difficult to enter micro-pores of a hypotonic oil reservoir or a dense oil reservoir, mainly plays a role in a main flow channel formed by a fracturing fluid, and limits the microscopic wave and volume of a system.
Patent CN113563861a discloses a microemulsion composition, nanoemulsion, and preparation method and application thereof. The provided nano emulsion can reduce the interfacial tension of oil and water, change the wettability of rock, reduce the adsorption quantity of surfactant, and can be used as a fracturing fluid additive for improving the seepage and oil recovery when a well is braised after fracturing a compact/shale reservoir stratum, thereby achieving the purpose of increasing the yield. The nonionic surfactant is at least one selected from OP-10, TX-4, tween80, span60 and AEO-9, and the conventional nonionic surfactant has cloud point and poor temperature resistance and is not suitable for high-temperature stratum. The anionic surfactant is at least one selected from SAS60 and LAS, AES, SDS, and is poor in salt tolerance and not suitable for high-salt stratum.
Microemulsions are thermodynamically stable systems that spontaneously form, and the mechanism of formation is very complex, with the key to preparation being the choice of the various pharmaceutical components and the proportions between them.
At present, the report of preparing microemulsion and being used for imbibition oil extraction is very few, and many traditional oilfield chemicals cannot meet the requirements of the oil extraction field on environmental protection due to higher toxicity and irritation, so that development of the environment-friendly low-toxicity biodegradable oil extraction agent is urgently needed.
Disclosure of Invention
The application aims to provide a microemulsion imbibition oil extraction agent. The oil extraction agent can improve the recovery ratio of a low-permeability oil reservoir or a dense oil reservoir through imbibition and can be biodegraded.
The application takes lactone type sophorolipid obtained by microbial fermentation as a raw material, and the lactone type sophorolipid is sulfonated to obtain sulfonated modified sophorolipid, and the sulfonated modified sophorolipid is compounded with alkylamide hydroxyl sulfobetaine to form a microemulsion imbibition oil extraction agent under the conditions of oil, water and cosurfactant, thereby improving the recovery ratio of low-permeability or compact oil reservoirs and guaranteeing the efficient development of oil fields.
The application also provides a preparation method of the microemulsion imbibition oil extraction agent.
The application also provides an application method of the microemulsion imbibition oil extraction agent.
In a first aspect, the present application provides a biodegradable microemulsion imbibition oil recovery agent, comprising, by mass of each component:
(1) 15-35 parts, preferably 18-30 parts, more preferably 20-26 parts, of alkylamidopropyl hydroxysulfonic acid betaine;
(2) 4-20 parts of modified sophorolipid sulfonate, preferably 6-16 parts, more preferably 8-14 parts;
(3) 5-18 parts, preferably 6-15 parts, more preferably 7-12 parts of cosurfactant;
(4) 3-25 parts, preferably 5-20 parts, more preferably 8-16 parts of an oil component;
(5) 30-70 parts, preferably 35-60 parts, more preferably 40-50 parts of saline water.
The alkylamide propyl hydroxysulfonic acid betaine has the following structural formula (1):
in the formula (1), R isFrom C 6 ～C 24 Any one of alkyl and alkenyl groups of (C) is preferable 8 ～C 20 Alkyl groups of (C) are most preferred 10 ～C 16 Normal alkyl of (a).
The modified sophorolipid sulfonate has the following structural formula (2):
in the formula (2), M + Is a cation selected from Li + 、Na + 、K + 、NH 4 + One or more of the following.
The modified sophorolipid sulfonate may be prepared according to a method well known to those skilled in the art, for example, by sulfonation of a lactone-type sophorolipid solution with sulfur trioxide at 60 to 90℃to obtain a sulfonated modified sophorolipid. Adding a proper amount of sodium hydroxide into the sulfonated modified sophorolipid, and regulating the pH value of the solution to be neutral or weak alkaline (pH value is 7.0-9.0) to obtain the modified sophorolipid sulfonate.
The cosurfactant is alcohol with 2-8 carbon atoms, preferably one or more of n-propanol, n-butanol, isopropanol and isobutanol.
The oil component is one or more of crude oil, solvent oil, alkane with 5-20 carbon atoms, kerosene and gasoline, preferably solvent oil and crude oil.
The salt-containing water is oil well produced water with the mineralization degree ranging from 12000mg/L to 40000mg/L, or tap water with the mass fraction of 12000mg/L to 40000mg/L of one or more inorganic salts, and the inorganic salts are preferably NaCl, KCl, naHCO 3 、Na 2 CO 3 Etc. The mass fraction of the inorganic salt is preferably 20000mg/L to 35000mg/L.
In a second aspect, the application provides a method of preparing a microemulsion imbibition oil recovery agent, the method comprising: dissolving sulfonated modified sophorolipid in saline water, adding a proper amount of alkali to adjust the pH of the solution to be neutral or weak alkaline (pH=7-9) to obtain modified sophorolipid sulfonate, adding alkylamide propyl hydroxysulfonic acid betaine, uniformly stirring, adding oil, adding cosurfactant, and uniformly mixing.
Preferably, the mixing conditions at least satisfy: the temperature is 10-40deg.C, and the stirring time is 10-60min.
In a third aspect, the present application provides a method of using a microemulsion imbibition oil recovery agent, the method comprising:
the microemulsion imbibition oil extraction agent provided by the application is prepared into a solution by using oilfield injection water, the mass fraction of the oil extraction agent in the solution is 5% -50%, preferably 10% -30%, the injection quantity of the microemulsion imbibition oil extraction agent is calculated according to the data such as the thickness of an oil reservoir, the permeability of a stratum, the treatment radius and the like, the microemulsion imbibition oil extraction agent solution is injected into the stratum from an oil well, the well is closed for 5-60 days, preferably 15-30 days, and then the well is opened for production.
Compared with the prior art, the application has the following advantages and beneficial effects:
(1) The application takes lactone type sophorolipid obtained by microbial fermentation as a raw material, the sulfonated modified sophorolipid is prepared by sulfonation reaction, and the sulfonated modified sophorolipid is compounded with alkylamide hydroxyl sulfobetaine to form the microemulsion imbibition oil extraction agent under the conditions of oil, water and cosurfactant. The microemulsion imbibition oil extraction agent can obviously improve the imbibition capacity of oil and water phases in an oil reservoir and can obviously improve imbibition recovery ratio of a hypotonic core.
(2) The microemulsion imbibition oil extraction agent has the advantages of simple preparation process, mild reaction condition and high yield, is particularly suitable for industrial production, and has remarkable economic benefit.
(3) The modified sophorolipid sulfonate and alkyl amide propyl hydroxyl sulfobetaine in the microemulsion imbibition oil extraction agent composition can be biodegraded, is environment-friendly, can reduce the pollution problem caused by chemical agents to the environment, and can bring greater environmental benefit on the basis of generating greater economic benefit.
Detailed Description
The endpoints and any values of the ranges disclosed herein are not limited to the precise range or value, and are understood to encompass values approaching those ranges or values. For numerical ranges, one or more new numerical ranges may be found between the endpoints of each range, between the endpoint of each range and the individual point value, and between the individual point value, in combination with each other, and are to be considered as specifically disclosed herein.
The lactone-type sophorolipids of the examples were purchased from Shandong Qilu Biotechnology group Co.
The dodecylamidopropyl hydroxysulfobetaine of the examples was purchased from Huainan Hua Jun New Material technologies Co.
In the following examples, unless otherwise specified, all reagents used were commercially available chemical reagents, and the sources of the reagents were not particularly limited.
Preparation example 1
Preparation of modified sophorolipid sulfonate GSH-1:
68.88g (100.0 mmol) of lactone type sophorolipid was dissolved in 500 ml of N, N-dimethylformamide and stirred continuously at 50℃until complete dissolution. Then, 0.2 mol of a sulfur trioxide pyridine complex was added thereto and reacted at 80℃for 4 hours. After the reaction is finished, removing the solvent by using a rotary evaporator to obtain the sulfonated modified sophorolipid GSH-1.
"each part" in the following examples means 1g.
Example 1
Preparation of microemulsion imbibition oil recovery composition JW-1:
sodium chloride and tap water are firstly used for preparing saline water with mass fraction of 35000mg/L. Taking 12 parts of sulfonated modified sophorolipid GSH-1, dissolving in 45 parts of saline water, adding a proper amount of sodium hydroxide to adjust the pH=7, adding 25 parts of dodecyl amide propyl hydroxysulfonic acid betaine, uniformly stirring, adding 10 parts of 200# solvent oil, adding 8 parts of n-propanol, and uniformly mixing to obtain the microemulsion JW-1.
Example 2
Preparation of microemulsion imbibition oil recovery composition JW-2:
firstly, preparing saline water with the mass fraction of 30000mg/L by using sodium chloride and tap water. 10 parts of sulfonated modified sophorolipid GSH-1 is taken and dissolved in 47 parts of saline water, a proper amount of sodium hydroxide is added to adjust the pH=7.5 of the solution, then 20 parts of tetradecylamide propyl hydroxysulfonic acid betaine is added, the mixture is stirred uniformly, 13 parts of 200# solvent oil is added, then 10 parts of n-propanol is added, and the mixture is mixed uniformly, thus obtaining the microemulsion JW-2.
Example 3
Preparation of microemulsion imbibition oil recovery composition JW-3:
sodium bicarbonate and tap water are firstly used for preparing the saline water with the mass fraction of 25000 mg/L. 6 parts of sulfonated modified sophorolipid GSH-1 is taken and dissolved in 48 parts of saline, a proper amount of sodium hydroxide is added to adjust the pH=7, then 30 parts of dodecyl amide propyl hydroxysulfonic acid betaine is added, the mixture is stirred uniformly, 8 parts of 200# solvent oil is added, and then 8 parts of n-propanol is added, and the mixture is mixed uniformly, thus obtaining the microemulsion JW-3.
Example 4
Preparation of microemulsion imbibition oil recovery composition JW-4:
firstly, preparing 20000mg/L saline water by using potassium chloride and tap water. Taking 5 parts of sulfonated modified sophorolipid GSH-1, dissolving in 47 parts of saline water, adding a proper amount of sodium hydroxide to adjust the pH=7.5, adding 17 parts of dodecyl amide propyl hydroxysulfonic acid betaine, uniformly stirring, adding 16 parts of 200# solvent oil, adding 15 parts of n-propanol, and uniformly mixing to obtain the microemulsion JW-4.
Example 5
Preparation of microemulsion imbibition oil recovery composition JW-5:
firstly, preparing the salt-containing water with the mass fraction of 12000mg/L by using calcium chloride and tap water. Taking 12 parts of sulfonated modified sophorolipid GSH-1, dissolving in 47 parts of saline water, adding a proper amount of sodium hydroxide to adjust the pH=8, adding 22 parts of dodecyl amide propyl hydroxysulfonic acid betaine, uniformly stirring, adding 12 parts of 200# solvent oil, adding 7 parts of n-propanol, and uniformly mixing to obtain the microemulsion JW-5.
Example 6
Preparation of microemulsion imbibition oil recovery composition JW-6:
sodium chloride and tap water are firstly used for preparing saline water with mass fraction of 35000mg/L. Taking 12 parts of sulfonated modified sophorolipid GSH-1, dissolving in 45 parts of saline water, adding a proper amount of sodium hydroxide to adjust the pH=7, adding 25 parts of dodecyl amide propyl hydroxysulfonic acid betaine, uniformly stirring, adding 10 parts of crude oil of a certain block of a victory oil field (the viscosity of the crude oil is 2.23 mPa.s at 50 ℃), adding 8 parts of n-propanol, and uniformly mixing to obtain the microemulsion JW-6.
Example 7
Preparation of microemulsion imbibition oil recovery composition JW-7:
sodium chloride and tap water are firstly used for preparing saline water with mass fraction of 35000mg/L. Taking 12 parts of sulfonated modified sophorolipid GSH-1, dissolving in 45 parts of saline water, adding a proper amount of sodium hydroxide to adjust the pH=7, adding 25 parts of dodecyl amide propyl hydroxysulfonic acid betaine, uniformly stirring, adding 10 parts of 200# solvent oil, adding 8 parts of n-butanol, and uniformly mixing to obtain the microemulsion JW-7.
Comparative example 1
In contrast to example 1, a brine solution having a mass fraction of 30000mg/L was prepared with sodium chloride and tap water. Taking 37 parts of dodecyl amide propyl hydroxyl sulfobetaine, dissolving in 45 parts of water, adding 10 parts of 200# solvent oil, adding 8 parts of n-propanol, and uniformly mixing. After standing, the mixture was in a layered state, the upper layer was about 8 parts of an oil phase, and the lower layer was about 92 parts of a uniform system. The lower homogeneous system, number DB-1, was separated using a separatory funnel.
Comparative example 2
In contrast to example 1, a brine solution having a mass fraction of 30000mg/L was prepared with sodium chloride and tap water. Taking 37 parts of sulfonated modified sophorolipid GSH-1, dissolving in 45 parts of water, adding a proper amount of sodium hydroxide to adjust the pH of the solution to be neutral or slightly alkaline (pH=7-9), adding 10 parts of 200# solvent oil, adding 8 parts of n-propanol, and uniformly mixing. After standing, the mixture was in a layered state, the upper layer was about 10 parts of the oil phase, and the lower layer was about 90 parts of the homogeneous system, and no microemulsion was considered to be formed. The lower homogeneous system, number DB-2, was separated using a separatory funnel.
Comparative example 3
In contrast to example 1, a mass fraction of 35000mg/L of saline water was first prepared with sodium chloride and tap water. 25 parts of sulfonated modified sophorolipid GSH-1 is taken and dissolved in 45 parts of saline water, a proper amount of sodium hydroxide is added to adjust the pH of the solution to be neutral or weak alkaline (pH=7-9), then 12 parts of dodecyl amide propyl hydroxysulfonic acid betaine is added, the mixture is stirred uniformly, 10 parts of 200# solvent oil is added, and then 8 parts of n-propanol is added, and the mixture is mixed uniformly. After standing, the mixture was in a layered state, the upper layer was about 5 parts of an oil phase, and the lower layer was about 95 parts of a uniform system. The lower homogeneous system, number DB-3, was separated using a separatory funnel.
Test example 1
Experimental conditions: the experimental oil is crude oil of a certain block of a victory oil field, and the viscosity of the experimental oil is 4.6 mPa.s at 50 ℃. The formation water mineralization used for the test was 30000mg/L. The microemulsion imbibition oil recovery composition was formulated as a 10% by mass solution using formation water, respectively.
The core treatment process comprises the following steps: 7 cores with diameters of 2.5cm and lengths of about 8cm are cut and polished on a piece of outcrop rock with wettability of hydrophilicity, and the cores are dried and related parameters of the cores including size, porosity and gas permeability are measured. Core gas permeability of about 15.3X10 -3 μm。
The testing process comprises the following steps: and (3) vacuumizing the rock core to saturate stratum water, then saturating oil, recording a saturated oil system, and aging for 24 hours. And (3) placing the core after the saturated oil into a water absorption instrument, then respectively filling stratum water or 10% microemulsion imbibition oil extraction agent composition solution in the water absorption instrument, placing the water absorption instrument into a constant temperature box, and carrying out self-absorption experiments at the constant temperature of 50 ℃. Under the imbibition effect, the core surface can discharge some oil globules, and the oil globules float to the surface of water, utilize the scale of water absorption appearance to directly read out the volume of water absorption oil extraction at different moments. The imbibition recovery ratio was calculated from the volume of water and oil absorbed and discharged for 5 days (120 hours). The test results are shown in Table 1.
Table 1 imbibition recovery of cores with different compositions
| Numbering device | Saturated oil volume/mL | volume/mL of water absorption and oil drainage | Imbibition recovery/% |
| Formation water | 6.65 | 0.68 | 10.23 |
| JW-1 | 6.70 | 2.11 | 31.49 |
| JW-2 | 6.60 | 1.95 | 29.55 |
| JW-3 | 6.65 | 1.64 | 24.66 |
| JW-4 | 6.65 | 1.43 | 21.50 |
| JW-5 | 6.60 | 1.74 | 26.36 |
| JW-6 | 6.72 | 2.09 | 31.10 |
| JW-7 | 6.61 | 2.01 | 30.41 |
| DB-1 | 6.68 | 1.15 | 17.22 |
| DB-2 | 6.62 | 1.08 | 16.31 |
| DB-3 | 6.73 | 1.28 | 19.02 |
As can be seen from Table 1, the microemulsion imbibition oil recovery agent of the application can obviously improve imbibition recovery ratio of the hypotonic core.
Claims (11)
1. A microemulsion imbibition oil recovery agent, comprising, by mass of each component:
(1) 15-35 parts of alkyl amide propyl hydroxysulfonic acid betaine;
(2) 4-20 parts of modified sophorolipid sulfonate;
(3) 5-18 parts of cosurfactant;
(4) 3-25 parts of an oil component;
(5) 30-70 parts of saline water.
2. The oil recovery agent according to claim 1, comprising, by mass of each component:
(1) 18-30 parts of alkylamidopropyl hydroxysulfonic acid betaine;
(2) 6-16 parts of modified sophorolipid sulfonate;
(3) 6-15 parts of cosurfactant;
(4) 5-20 parts of an oil component;
(5) 35-60 parts of brine.
3. The oil recovery agent according to claim 1, comprising, by mass of each component:
(1) 20-26 parts of alkyl amide propyl hydroxysulfonic acid betaine;
(2) 8-14 parts of modified sophorolipid sulfonate;
(3) 7-12 parts of cosurfactant;
(4) 8-16 parts of oil components;
(5) 40-50 parts of saline water.
4. The oil recovery agent of claim 1 wherein said alkylamidopropyl hydroxysulfonic acid betaine has the following structural formula:
wherein R is selected from C 6 ～C 24 Any one of alkyl and alkenyl groups of (C) is preferable 8 ～C 20 Alkyl groups of (C) are most preferred 10 ～C 16 Normal alkyl of (a).
5. The oil recovery agent according to claim 1, wherein the modified sophorolipid sulfonate has the following structural formula:
wherein M is + Is a cation selected from Li + 、Na + 、K + 、NH 4 + One or more of the following.
6. The oil extraction agent according to claim 1, wherein the cosurfactant is an alcohol with 2-8 carbon atoms, preferably one or more of n-propanol, n-butanol, isopropanol and isobutanol.
7. The oil extraction agent according to claim 1, wherein the oil component is one or more of crude oil, solvent oil, alkane with 5-20 carbon atoms, kerosene and gasoline, preferably solvent oil and crude oil.
8. The oil extraction agent according to claim 1, wherein the salt-containing water is produced water from oil well having a mineralization degree in the range of 12000mg/L to 40000mg/L, or tap water to which one or more inorganic salts selected from NaCl, KCl, naHCO are added in a mass fraction of 12000mg/L to 40000mg/L 3 、Na 2 CO 3 。
9. A method of preparing the microemulsion imbibition oil recovery agent of any one of claims 1-8, comprising:
dissolving sulfonated modified sophorolipid in saline, adding a proper amount of alkali to adjust the pH of the solution to be neutral or weak alkaline to obtain modified sophorolipid sulfonate, adding alkylamide propyl hydroxysulfonic acid betaine, uniformly stirring, adding oil, adding cosurfactant and uniformly mixing.
10. The method of claim 9, wherein the mixing conditions at least satisfy: the temperature is 10-40deg.C, and the stirring time is 10-60min.
11. A method of using a microemulsion imbibition oil recovery agent, comprising: using oil field to inject water, preparing the microemulsion imbibition oil extraction agent as solution, wherein the mass fraction of the oil extraction agent in the solution is 5% -50%, injecting the microemulsion imbibition oil extraction agent solution into the stratum from the oil well, closing the well for 5-60 days, and then opening the well for production.
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