CN116554852B - Method for inhibiting viscosity index of water flooding in porous medium - Google Patents
Method for inhibiting viscosity index of water flooding in porous medium Download PDFInfo
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- CN116554852B CN116554852B CN202310525721.3A CN202310525721A CN116554852B CN 116554852 B CN116554852 B CN 116554852B CN 202310525721 A CN202310525721 A CN 202310525721A CN 116554852 B CN116554852 B CN 116554852B
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 72
- 238000000034 method Methods 0.000 title claims abstract description 26
- 230000002401 inhibitory effect Effects 0.000 title claims abstract description 9
- 239000002105 nanoparticle Substances 0.000 claims abstract description 56
- 239000003921 oil Substances 0.000 claims abstract description 39
- 239000004094 surface-active agent Substances 0.000 claims abstract description 28
- 229920000642 polymer Polymers 0.000 claims abstract description 15
- 230000008569 process Effects 0.000 claims abstract description 10
- 239000010779 crude oil Substances 0.000 claims abstract description 6
- 239000012071 phase Substances 0.000 claims description 45
- 239000004205 dimethyl polysiloxane Substances 0.000 claims description 12
- 229920000435 poly(dimethylsiloxane) Polymers 0.000 claims description 12
- -1 polydimethylsiloxane Polymers 0.000 claims description 12
- 239000004793 Polystyrene Substances 0.000 claims description 11
- 229920002223 polystyrene Polymers 0.000 claims description 10
- 239000008346 aqueous phase Substances 0.000 claims description 5
- DCAYPVUWAIABOU-UHFFFAOYSA-N hexadecane Chemical compound CCCCCCCCCCCCCCCC DCAYPVUWAIABOU-UHFFFAOYSA-N 0.000 claims description 4
- 125000003178 carboxy group Chemical group [H]OC(*)=O 0.000 claims description 3
- 239000008367 deionised water Substances 0.000 claims description 2
- 229910021641 deionized water Inorganic materials 0.000 claims description 2
- 125000000118 dimethyl group Chemical group [H]C([H])([H])* 0.000 claims description 2
- 239000002245 particle Substances 0.000 claims description 2
- 239000000377 silicon dioxide Substances 0.000 claims description 2
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 2
- 229920002545 silicone oil Polymers 0.000 claims description 2
- 239000013543 active substance Substances 0.000 claims 1
- YENOLDYITNSPMQ-UHFFFAOYSA-N carboxysilicon Chemical compound OC([Si])=O YENOLDYITNSPMQ-UHFFFAOYSA-N 0.000 claims 1
- 125000000524 functional group Chemical group 0.000 claims 1
- 235000012239 silicon dioxide Nutrition 0.000 claims 1
- 238000006073 displacement reaction Methods 0.000 abstract description 45
- 230000007547 defect Effects 0.000 abstract description 4
- 238000011084 recovery Methods 0.000 abstract description 4
- 150000003839 salts Chemical class 0.000 abstract description 4
- 239000003795 chemical substances by application Substances 0.000 abstract description 2
- 230000004888 barrier function Effects 0.000 description 6
- 239000003086 colorant Substances 0.000 description 6
- 239000012530 fluid Substances 0.000 description 5
- 238000007789 sealing Methods 0.000 description 5
- 239000007864 aqueous solution Substances 0.000 description 4
- AMTWCFIAVKBGOD-UHFFFAOYSA-N dioxosilane;methoxy-dimethyl-trimethylsilyloxysilane Chemical compound O=[Si]=O.CO[Si](C)(C)O[Si](C)(C)C AMTWCFIAVKBGOD-UHFFFAOYSA-N 0.000 description 4
- MCPLVIGCWWTHFH-UHFFFAOYSA-L methyl blue Chemical compound [Na+].[Na+].C1=CC(S(=O)(=O)[O-])=CC=C1NC1=CC=C(C(=C2C=CC(C=C2)=[NH+]C=2C=CC(=CC=2)S([O-])(=O)=O)C=2C=CC(NC=3C=CC(=CC=3)S([O-])(=O)=O)=CC=2)C=C1 MCPLVIGCWWTHFH-UHFFFAOYSA-L 0.000 description 4
- 229940083037 simethicone Drugs 0.000 description 4
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 230000009545 invasion Effects 0.000 description 3
- 238000012360 testing method Methods 0.000 description 3
- 230000008859 change Effects 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 239000003550 marker Substances 0.000 description 2
- 238000010587 phase diagram Methods 0.000 description 2
- 230000005501 phase interface Effects 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 238000001179 sorption measurement Methods 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 239000001045 blue dye Substances 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011549 displacement method Methods 0.000 description 1
- 239000000975 dye Substances 0.000 description 1
- 229910021389 graphene Inorganic materials 0.000 description 1
- 238000010191 image analysis Methods 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 239000004005 microsphere Substances 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 239000002135 nanosheet Substances 0.000 description 1
- 239000002077 nanosphere Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 125000002924 primary amino group Chemical group [H]N([H])* 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 230000011218 segmentation Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
Classifications
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- 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
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- 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
- C09K2208/10—Nanoparticle-containing well treatment fluids
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A20/00—Water conservation; Efficient water supply; Efficient water use
- Y02A20/20—Controlling water pollution; Waste water treatment
- Y02A20/204—Keeping clear the surface of open water from oil spills
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Abstract
The invention relates to the technical field of oil displacement agents for improving the recovery ratio of crude oil, in particular to a method for inhibiting viscous fingering of water displacement in a porous medium. In the invention, the surface functionalized nano-particles in the water phase and the functionalized group polymer in the oil phase react at the oil-water interface to generate the surface active substance adsorbed on the oil-water interface, which is called nano-particle surfactant, and the nano-particle surfactant can induce the viscoelasticity of the oil-water interface, thereby inhibiting the viscous finger-in phenomenon in the water flooding process in the porous medium and remarkably improving the water flooding efficiency. The invention can effectively solve the defects of high cost, poor temperature resistance and salt resistance and the like of the traditional polymer system and the nanoparticle system, and has wide prospect in the engineering application of improving the crude oil recovery ratio.
Description
Technical Field
The invention relates to the technical field of oil displacement agents for improving the recovery ratio of crude oil, in particular to a method for inhibiting viscous fingering of water displacement in a porous medium.
Background
In the oil reservoir exploitation process, when the viscosity of the invasion fluid (usually water) and the viscosity of the oil phase in the oil reservoir porous medium reservoir are large, the invasion fluid rapidly breaks through in the reservoir along the displacement direction to form a finger-shaped dominant channel, so that the invasion fluid in other areas has insufficient pressure to displace the oil layer, and the sweep efficiency is reduced. This unstable phenomenon at the leading edge of the displacement interface due to the displacement of high viscosity fluid by low viscosity fluid is known as the viscous finger-in effect. The polymer is added into the water phase to improve the viscosity of the water phase, reduce the oil-water viscosity ratio and inhibit viscous fingering, but the concentration of the polymer to be added is high, and the polymer molecules are easy to lose effectiveness in a high-temperature and high-salt environment of the oil reservoir. Viscous fingering can be inhibited by changing wall wettability and porous medium structure, but the viscous fingering is difficult to apply in actual oil reservoir exploitation. In recent years, researchers have adopted amphiphilic graphene nano sheets to be adsorbed on an oil-water interface to form an elastic film, so that viscous fingering in a porous medium can be effectively inhibited, the water displacement efficiency in a rock core is remarkably improved, and the method has the defects of high cost, poor temperature resistance, poor salt resistance and the like.
Disclosure of Invention
The invention aims to overcome the defects of the prior art and provide a method for inhibiting the viscosity index of water flooding in a porous medium, which is characterized in that the viscosity index of water flooding in the porous medium is inhibited by a nanoparticle surfactant with strong temperature resistance and salt resistance and difficult failure.
In order to achieve the purpose, the invention is realized by adopting the following technical scheme:
A method of inhibiting water flooding viscous fingering in a porous medium comprising the operations of:
Mixing the water phase and the oil phase in the porous medium, and reacting the surface functionalized nano particles in the water phase with the functionalized group polymer in the oil phase at the oil-water interface to generate a surface active substance adsorbed on the oil-water interface, namely a nano particle surfactant, wherein the generated nano particle surfactant induces viscoelasticity of the oil-water interface, so that viscous fingering in the water flooding process in the porous medium is inhibited.
Further, the surface functionalized nanoparticle is a carboxyl silica nanoparticle or a carboxyl polystyrene nanoparticle; and/or
The particle size of the surface functionalized nano particles is smaller than 100nm; and/or
The concentration of surface functionalized nanoparticles in the aqueous phase is from 0.001wt.% to 0.1wt.%.
Further, the concentration of the surface functionalized nanoparticles is 0.01wt.%, and the aqueous phase is deionized water.
Further, the functionalized group polymer is mono-amino end-blocked polydimethylsiloxane or di-amino end-blocked polydimethylsiloxane; and/or
The concentration of the functionalized group polymer in the oil phase is 0.05wt.% to 5wt.%; and/or
The oil phase is dimethyl silicone oil, n-hexadecane or crude oil.
Compared with the prior art, the invention has the following beneficial effects:
The invention provides a method for inhibiting viscosity index of water flooding in a porous medium, which is characterized in that modified nano particles dispersed in water and a diamino end-sealing polymer in oil react at an oil-water interface to generate a nano particle surfactant, so that the adsorption stability of the nano particles is obviously improved, the interfacial viscoelasticity is improved, and the oil-water interfacial tension is reduced. The nanoparticle surfactant effectively improves the displacement efficiency by reducing the interfacial tension, inhibits the viscous fingering phenomenon, and further improves the recovery ratio. On the other hand, the displacement efficiency is further improved by adopting the method of generating the surfactant in situ in the reservoir.
Drawings
FIG. 1 is a representation of a porous media model designed in accordance with the present invention;
FIG. 2 is a schematic illustration of the water flooding of the present invention within a porous media model;
FIG. 3 is a graph of the present invention showing the change in nanoparticle surfactant, pure nanoparticle, and water flooding displacement efficiency over time for the same capillary number;
FIG. 4 is a graph comparing the displacement efficiency of the nano-particle surfactant and water flooding at different viscosity ratios for the same capillary number measured in accordance with the present invention;
Fig. 5 is a phase diagram of a measured nanoparticle surfactant and water flooding displacement pattern according to the present invention.
Detailed Description
In order that those skilled in the art will better understand the present invention, a technical solution in the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in which it is apparent that the described embodiments are only some embodiments of the present invention, not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the present invention without making any inventive effort, shall fall within the scope of the present invention.
It should be noted that the terms "first," "second," and the like in the description and the claims of the present invention and the above figures are used for distinguishing between similar objects and not necessarily for describing a particular sequential or chronological order. It is to be understood that the data so used may be interchanged where appropriate such that the embodiments of the invention described herein may be implemented in sequences other than those illustrated or otherwise described herein. Furthermore, the terms "comprises," "comprising," and "having," and any variations thereof, are intended to cover a non-exclusive inclusion, such that a process, method, system, article, or apparatus that comprises a list of steps or elements is not necessarily limited to those steps or elements expressly listed but may include other steps or elements not expressly listed or inherent to such process, method, article, or apparatus.
The invention develops and constructs the nanoparticle surfactant system based on the adsorption of the functionalized substance on the oil-water interface, and can effectively solve the defects of high cost, poor temperature resistance and salt resistance and the like of the traditional polymer system and the nanoparticle system.
The invention provides a nanoparticle surfactant oil displacement system for petroleum exploitation, which is characterized in that carboxyl polystyrene nanoparticles dispersed in water and a diamino end-sealing polymer in oil react at an oil-water interface to generate nanoparticle surfactant, so that interfacial viscoelasticity is induced, the tension of the oil-water interface is reduced, and the viscous finger-in phenomenon in the water oil displacement process in a porous medium is inhibited.
The invention is described in further detail below with reference to the attached drawing figures:
Because the reservoir structure is mainly porous medium, the reservoir environment is simulated by adopting a porous medium model. The model uses PDMS (polydimethylsiloxane) as a chip material, and has good hydrophobicity and chemical stability. The simethicone simulates crude oil, is colorless and transparent, and is convenient for observation. By adopting the oil displacement method, the modified nanoparticle surfactant is generated at the oil-water interface to carry out oil displacement, and the image is acquired in real time and analyzed in phase distribution in the oil displacement process so as to test the oil displacement efficiency of the invention. The specific implementation steps are as follows:
(1) Adopting a syringe pump to saturate the oil phase with the porous medium model;
The oil phase contains 0.1% by mass of double amino end group polydimethylsiloxane (NH 2-PDMS-NH2, sigma-Aldrich, molecular weight 2500, density 0.98 g/mL) and 1wt.% Sudan I dye as a marker;
A porous media chip design is shown in fig. 1. The area range of the porous medium of the chip is 30 multiplied by 15mm, the inlet and outlet are small holes with the diameter of 0.8mm, the thickness of the test section is 160 mu m, the porosity is 56%, the circular barriers are arranged in a regular hexagon, the radius of the circular barriers is 0.2mm, and the center distance of the circular barriers is 0.6mm;
(2) After saturation, taking the aqueous solution as a displacement phase, displacing oil phases in the porous medium with different capillary numbers, and after the water phases break through the porous medium part, forming an advantage channel, ensuring that the oil-water interface is not changed any more;
The aqueous phase contains carboxyl-functionalized polystyrene nanoparticles (COOH-PS, microspheres nanospheres, concentration 2.5 wt.%) in a mass fraction of 0.01% and contains 1wt.% methyl blue dye as a marker;
capillary number ca=μv/σ, where μ is the displacement phase viscosity and σ is the interfacial tension; v is darcy's velocity, obtained by dividing the flow rate by the cross section of the porous medium region;
(3) And in the oil displacement process, utilizing microscopic image analysis software to acquire images in real time and analyze phase distribution. And calculating the displacement efficiency of the experimental group under different working conditions through images, and comparing the displacement efficiencies of the nanoparticle surfactant, the pure nanoparticle and the water drive under the same capillary number.
The displacement efficiency is calculated in an image analysis process based on a binary method, and specifically comprises the following steps:
Converting the picture into a gray level image, then carrying out binarization processing through threshold segmentation calculation, and converting the image into a black-white binary image from the gray level image. And dividing the number of black pixel points by the number of pixel points with the total aperture area to obtain the displacement efficiency.
Example 1:
The method comprises the steps of installing an injector on a microfluidic injection pump, using the injector to saturate a simethicone (oil phase viscosity is 1000 mPas, 1wt.% of Sudan I coloring agent and 0.1wt.% of double-amino-end-sealing polydimethylsiloxane) into a porous medium model, replacing the injector by a chip inlet capillary after saturation, using an aqueous solution (water phase viscosity is 1 mPas, 1wt.% of methyl blue coloring agent and 0.01wt.% of carboxylated polystyrene nano particles) as a displacement phase, displacing the oil phase in the porous medium by a capillary number Ca=1.6X10 -5, waiting for the water phase to break through a porous medium part, and forming a dominant channel, wherein the oil-water interface is not changed any more.
Example 2:
The method comprises the steps of installing an injector on a microfluidic injection pump, using the injector to saturate a simethicone (oil phase viscosity is 200 mPas, 1wt.% of Sudan I coloring agent and 0.1wt.% of double-amino-end-sealing polydimethylsiloxane) into a porous medium model, replacing the injector by a chip inlet capillary after saturation, using an aqueous solution (water phase viscosity is 1 mPas, 1wt.% of methyl blue coloring agent and 0.01wt.% of carboxylated polystyrene nano particles) as a displacement phase, displacing the oil phase in the porous medium by a capillary number Ca=1.6X10 -5, waiting for the water phase to break through a porous medium part, and forming a dominant channel, wherein the oil-water interface is not changed any more.
Example 3:
The method comprises the steps of installing an injector on a microfluidic injection pump, using the injector to saturate a simethicone (oil phase viscosity is 1000 mPas, 1wt.% of Sudan I coloring agent and 0.1wt.% of double-amino-end-sealing polydimethylsiloxane) into a porous medium model, replacing the injector by a chip inlet capillary after saturation, using an aqueous solution (water phase viscosity is 1 mPas, 1wt.% of methyl blue coloring agent and 0.01wt.% of carboxylated polystyrene nano particles) as a displacement phase, displacing the oil phase in the porous medium by a capillary number Ca=3.2X10 -5, waiting for the water phase to break through a porous medium part, and forming a dominant channel, wherein the oil-water interface is not changed any more.
Referring to fig. 1, fig. 1 is a porous media model designed according to the present invention; the area range of the porous medium of the chip is 30 multiplied by 15mm, the inlet and outlet are small holes with the diameter of 0.8mm, the thickness of the test section is 160 mu m, the porosity is 56%, the circular barriers are arranged in regular hexagons, the radius of the circular barriers is 0.2mm, and the center distance of the circular barriers is 0.6mm.
Referring to fig. 2, fig. 2 is a schematic illustration of displacement of oil within a porous media model according to the present invention; the main areas in fig. 2 are porous medium areas in the model, the light areas are the pores of the matrix and the filled oil phase, and the dark areas are the pores of the filled water phase. The displacement direction is from left to right, the initial water phase of displacement is used for stably displacing the oil phase, a dominant channel is gradually generated along with time, the oil-water interface is not changed after the water phase breaks through the porous medium, and the water phase flows along the dominant channel to reach a stable state.
Referring to fig. 3, fig. 3 is a graph showing the change of the displacement efficiency of the nanoparticle surfactant, the pure nanoparticle and the water flooding with time (carboxylated polystyrene nanoparticle concentration is 0.01wt.%, amino-terminal polydimethylsiloxane concentration is 0.1wt.%, oil-water viscosity ratio m=1000, ca=3.7x10 -5) under the same capillary number, and the final displacement efficiencies of the nanoparticle surfactant group, the pure nanoparticle group and the water flooding group are 86.17%, 31.57% and 25.82%, respectively, and the displacement efficiency of the nanoparticle surfactant is the best.
Fig. 4 is a graph showing the comparison of the displacement efficiency of the nanoparticle surfactant and water drive under the condition of the same displacement flow and different viscosity ratios (the concentration of the carboxylated polystyrene nanoparticles is 0.01wt.%, the concentration of the amino-terminal polydimethylsiloxane is 0.1wt.%, the flow rate Q=50 mu L/min), and the displacement efficiency of the nanoparticle surfactant is improved by more than 20 percent from 20 to 500 in the oil-water viscosity ratio M.
Fig. 5 is a phase diagram of the nanoparticle surfactant and water-flooding displacement pattern measured according to the present invention (carboxylated polystyrene nanoparticle concentration of 0.01wt.%, amino-terminated polymer concentration of 0.1 wt.%). The solid line is the nanoparticle surfactant phase interface and the long dashed line is the water drive phase interface. The displacement mode is divided into capillary finger-feeding and viscous finger-feeding, the capillary finger-feeding is mainly based on capillary force, an interface grows around during displacement, an dominant channel is not obvious, the displacement mode has the characteristic of high displacement efficiency, the viscous finger-feeding is mainly based on viscous force, the displacement is that the interface grows along the displacement direction, the dominant channel is formed, and the displacement efficiency is low. The nanoparticle surfactant is inhibited from viscous finger-in effects as compared to water flooding.
The above is only for illustrating the technical idea of the present invention, and the protection scope of the present invention is not limited by this, and any modification made on the basis of the technical scheme according to the technical idea of the present invention falls within the protection scope of the claims of the present invention.
Claims (1)
1. A method for inhibiting water flooding viscosity fingering in a porous medium is characterized by comprising the following steps:
Mixing the water phase and the oil phase, wherein surface functionalized nano-particles in the water phase and functionalized group polymer in the oil phase react at an oil-water interface to generate surface active substances adsorbed on the oil-water interface, namely nano-particle surfactant, and the generated nano-particle surfactant induces viscoelasticity of the oil-water interface, so that viscous fingering in a water flooding process in a porous medium is inhibited;
The surface functionalized nano-particles are carboxyl silicon dioxide nano-particles or carboxyl polystyrene nano-particles; and/or
The particle size of the surface functionalized nano particles is smaller than 100nm; and/or
The concentration of surface functionalized nanoparticles in the aqueous phase is 0.001wt.% to 0.1wt.%; and/or
The concentration of the surface functionalized nano particles is 0.01wt.%, and the aqueous phase is deionized water;
the functional group polymer is mono-amino end-blocked polydimethylsiloxane or di-amino end-blocked polydimethylsiloxane; and/or
The concentration of the functionalized group polymer in the oil phase is 0.05wt.% to 5wt.%; and/or
The viscosity of the oil phase is 10-1000 mPa.s at normal temperature, and the oil phase is dimethyl silicone oil, n-hexadecane or crude oil.
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| US8822386B2 (en) * | 2010-06-28 | 2014-09-02 | Baker Hughes Incorporated | Nanofluids and methods of use for drilling and completion fluids |
| US10392555B2 (en) * | 2015-12-18 | 2019-08-27 | International Business Machines Corporation | Nanoparticle design for enhanced oil recovery |
| CN110573591A (en) * | 2016-10-06 | 2019-12-13 | 杜兰教育基金委员会 | Water-soluble micelles for delivery of oil-soluble materials |
| CN109403932B (en) * | 2017-08-16 | 2021-11-30 | 中国石油化工股份有限公司 | Oil displacement method for reducing adsorption loss |
| WO2020191491A1 (en) * | 2019-03-27 | 2020-10-01 | Uti Limited Partnership | Nanoparticle-surfactant stabilized foams |
| CN110079291B (en) * | 2019-05-31 | 2020-02-18 | 西南石油大学 | High-phase-transition-point-containing in-situ emulsification and viscosification system and application thereof in water-drive oil reservoir |
| CN117487534A (en) * | 2019-11-28 | 2024-02-02 | 株式会社Inpex | Silica nanoparticles for recovery of crude oil using carbon dioxide and crude oil recovery process |
| US11708274B2 (en) * | 2020-04-15 | 2023-07-25 | Saudi Arabian Oil Company | Synthesis of polyethylenimine-silica janus nanoparticles |
| US20220145165A1 (en) * | 2020-05-20 | 2022-05-12 | University Of Wyoming | Quantum dot nanofluids |
| US11827850B2 (en) * | 2020-07-24 | 2023-11-28 | Saudi Arabian Oil Company | Enhanced oil recovery with janus nanoparticles |
| CN114456787A (en) * | 2020-10-21 | 2022-05-10 | 中国石油化工股份有限公司 | Double-group modified water-based nano silicon material and preparation method and application thereof |
| CN112266775B (en) * | 2020-10-23 | 2022-07-01 | 西南石油大学 | Preparation of in-situ nano emulsifier and oil reservoir application method |
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| Cui M ; Emrick T, Russell T P. .Stabilizing Liquid Drops in Nonequilibrium Shapes by the Interfacial Jamming of Nanoparticles. Science.2013,图1、图4及正文部分第3段、倒数第3段. * |
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