CN105315982A - System of three-phase enhanced foam oil displacement after two-component compound oil displacement - Google Patents
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- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
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- 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
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- 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
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Abstract
The invention discloses a system of three-phase enhanced foam oil displacement after two-component compound oil displacement. The system comprises a liquid phase, a solid phase and a gas phase, wherein the liquid phase comprises one or more foaming agents, one or two foam stabilizers and water; the solid phase comprises a polyethylene imine gel system and an inorganic nanometer material; the gas phase is selected from nitrogen, air or carbon dioxide; the consumption of the foaming agents accounts for 0.05-5% of the mass of the liquid phase; the consumption of the foam stabilizers accounts for 0.1-3% of the mass of the liquid phase; the consumption of the inorganic nanometer material accounts for 0.2-3% of the mass of the liquid phase; the consumption of the polyethylene imine gel system accounts for 0.05-1% of the mass of the liquid phase; the volume ratio of the gas phase to the liquid phase is (1-3):1. The system provided by the invention can remarkably improve the efficiency of oil recovery after two-component compound oil displacement.
Description
Technical field
The invention belongs to field of petroleum exploitation, relate to three-phase forced foam flooding system after a kind of binary combination flooding.
Background technology
Oil is very important a kind of non-renewable energy that the current whole world uses, and the proportion that its Year's consumption accounts for all energy-output ratios is increasing year by year, and thus the raising of oil recovery becomes the problem that the whole society pays special attention to.Current oil production is mainly faced with contradiction between oil supply and demand and becomes increasingly conspicuous, and new discovery oil field is fewer and feweri and developed in maturing field the problem still having a large amount of surplus oil can not exploit.In oil-field development, by the underground crude oil of 25 ~ 50% generally can only be exploited out after primary oil recovery and secondary oil recovery, still remain substantial oil in oil reservoir and needed to be exploited further.
After secondary oil recovery, due to the raising of recovery percent of reserves, remaining oil distribution is more scattered, and the nonuniformity of oil reservoir is aggravated further, thus adds the difficulty of exploitation.In order to improve the recovery ratio in existing oil field, tertiary oil recovery technology obtains to be applied more widely.Binary combination flooding oil tech is the important means improving recovery ratio in tertiary oil recovery technology, but in the middle and later periods of oil-field development, owing to being subject to the impact of reservoir heterogeneity, mobility on longitudinal in stratum differs greatly, Character of Viscous Finger is more and more serious, chemical agent can not arrive the position of remaining oil enrichment completely, can not drive fully and wash crude oil, thus causes the ultimate recovery factor of binary combination flooding to receive restriction to a certain degree.
Foam flooding is the method utilizing the foam performance of tensio-active agent to be made into foam flooding finish to carry out recovering the oil.The feature that foam flooding chance water is stablized, meet oil shattered to pieces makes it be provided with selectively blocking off ability to profit, thus in the research improving oil recovery factor, more and more comes into one's own.Strengthening foam is the foam formed add certain density polymkeric substance in water-based foam after, compared to the advantage of water-based foam, strengthening foam is that the steady bubble ability of strengthening foam is stronger, polymkeric substance is joined after in water based foam system, polymkeric substance can increase liquid phase viscosity, thus add the mechanical stability of bubble film, make foam have the longer transformation period; And due to adding of polymkeric substance, liquid phase viscosity is increased, thus effectively slow down the drain age velocity between bubble film, hinder thinning of liquid film, occur co-adsorption at gas/liquid interface pore forming material and polymer molecule, cause the liquid film discharge opeing phase elongated, thus significantly enhance the stability of foam.
Three-phase froth is the dispersion system mixture formed through foaming by solid, liquid, gas.The outstanding feature that three-phase froth is driven is exactly more stable than the foam of gas/liquid two-phase foam flooding generation, and along with the increase of rate of permeation, the apparent viscosity of foam increases, effectively can adjust the mobility difference of most permeable zone and low permeability layer, thus reach most permeable zone and low permeability layer employs exploitation simultaneously, realize the mobility displacements such as stratum, and then improve sweep efficiency and ultimate recovery factor.Therefore, develop a kind of efficient three-phase froth oil recovery system the tail period in oil field is of great immediate significance.
Summary of the invention
In order to solve the problems of the technologies described above, the technical solution used in the present invention is as follows:
Three-phase forced foam flooding system after a kind of binary combination flooding, by liquid phase, the gentle phase composite of solid phase, wherein, liquid phase is made up of pore forming material, suds-stabilizing agent and water; Solid phase is made up of polymine jelly system and inorganic nano material; Gas phase is selected from nitrogen, air or carbonic acid gas;
The consumption of described pore forming material is the 0.05-5% of liquid phase quality, and the consumption of described suds-stabilizing agent is the 0.1-3% of liquid phase quality, and the consumption of inorganic nano material is the 0.2-3% of liquid phase quality, and the consumption of polymine jelly system is the 0.05-1% of liquid phase quality; The volume ratio of gas phase and liquid phase is 1-3:1;
Described pore forming material be selected from polyoxyethylene nonylphenol ether, sorbitan monooleate Soxylat A 25-7, fatty acid methyl ester ethoxylate, Sodium dodecylbenzene sulfonate one or more;
The structure of polyoxyethylene nonylphenol ether is as follows:
Wherein, n is polyoxyethylated mole number;
The structure of sorbitan monooleate Soxylat A 25-7 is as follows:
Wherein, x
1+ y
1+ z
1=20-25, R are CH
3(CH
2)
7-CH=CH-(CH
2)
7-;
The structure of fatty acid methyl ester ethoxylate is as follows:
The structure of Sodium dodecylbenzene sulfonate is as follows:
Described suds-stabilizing agent be selected from polyacrylamide and polyvinyl alcohol one or more; Wherein, the molecular weight of described polyacrylamide is 1000-2000 ten thousand, and degree of hydrolysis is 5-15%; The molecular weight of polyvinyl alcohol is 20-40 ten thousand;
Described inorganic nano material is selected from carbon nanotube, nano zine oxide, nano silicon, nano titanium oxide, nano-calcium carbonate; Described inorganic nano material is of a size of 20-50nm;
Described polymine jelly system is reacted by partially hydrolyzed polyacrylamide and linking agent polymine and is formed, calculate by percentage to the quality, comprise following component: partially hydrolyzed polyacrylamide 0.1 ~ 0.8%, linking agent polymine 0.1 ~ 0.6%, additive 0.2 ~ 1%, surplus is water; Wherein, what partially hydrolyzed polyacrylamide adopted is anion-polyacrylamide, and the molecular weight of this anion-polyacrylamide is 5,000,000 ~ 1,600 ten thousand, degree of hydrolysis 4% ~ 20%, and solid content is greater than 90%; The molecular weight of linking agent polymine is 5000-20000, solid content 30% ~ 60%; Described additive is selected from one or more of S-WAT, sodium bisulfite, Sulfothiorine and thiocarbamide.
The preparation method of three-phase forced foam flooding system after described a kind of binary combination flooding, comprise: proportionally, suds-stabilizing agent is added in water, stir 5-10min, after it fully dissolves, add polymine jelly system and inorganic nano material, stir 5-10min and treat that it is uniformly dispersed, then add pore forming material and to stir obtained flooding system solution; Flooding system solution and gas are passed into foam generated in rock core.
The beneficial effect of three-phase forced foam flooding system of the present invention:
(1) the three-phase forced foam flooding system prepared by the present invention is the mixture with certain dispersion system formed through foaming by gas, solid, liquid three-phase.Three-phase strengthening foam good stability prepared by the present invention, has higher seepage resistance, can force the zone flows injected fluid and do not involve to binary combination flooding, thus expand swept volume, improve the development efficiency in oil field, increase the overall recovery factor in oil field.
(2) compound system of Organic Solid-Phase (the polymer gel)+inorganic solid phase (inorganic nano material) of solid phase employing of the present invention, has the features such as froth stability is good, strong adaptability, viscosity are high, suspension property good, plugging strength is large.
(3) three-phase enhanced foam flooding of the present invention can make up the defect of binary combination flooding, shutoff can be produced to preferential path or macropore, can oil and water mobility ratio be reduced again, improve sweep efficiency and displacement efficiency, thus significantly improve the ultimate recovery factor of crude oil.
Accompanying drawing explanation
Fig. 1 is according to three-phase froth oil displacement experiment equipment schematic diagram after binary combination flooding of the present invention.
Wherein, 1,2: constant-flux pump; 3: gas cylinder; 4: valve; 5: precision pressure gauge; 6: gas tank; 7: water pot; 8: binary composite oil displacement agent tank; 9: three-phase froth oil-displacing agent tank; 10: oil tank; 11: six-way valve; 12: core holding unit; 13: thermostat container; 14: back pressure controller; 15: wobble pump; 16: measuring apparatus.
Embodiment
Below by embodiment, the present invention is further elaborated.
Experiment is carried out according to petroleum industry standard SY/T6424-2000 composite oil-displacing system performance test methods.
The present invention adopts core oil-displacement test, rock core basic parameter: length × wide × height=30cm × 4.5cm × 4.5cm; Crude oil is ground dehydration gas-free oil, viscosity 92.1mPas at 70 DEG C; Simulated formation water: NaHCO
3type solution, salinity 7650mg/L, temperature: 70 DEG C.
The binary combination flooding oil systems that this experiment uses can be conventional polymkeric substance and tensio-active agent, and wherein, described polymkeric substance can be water-soluble polyacrylamide polymkeric substance; Described tensio-active agent can be in cationic surfactant, aniorfic surfactant, nonionic surface active agent one or more, such as can select Sodium dodecylbenzene sulfonate.
Three-phase forced foam flooding system of the present invention, adopt the experimental installation shown in Fig. 1 to carry out core oil-displacement test, its basic step is: first by rock core vacuumizing, saturation simulation local water; With the speed of 0.8mL/min, simulated formation water is injected rock core, calculate rock pore volume; With the Velocity saturation ground of 0.1mL/min dehydration gas-free oil, until exit end production fluid is all oil, calculate initial oil saturation; Be that 0.8mL/min carries out water drive experiment with injection speed, until water ratio is 98% in production fluid, the binary combination flooding oil systems solution of certain volume of voids is now injected again with the injection speed of 0.1mL/min, then water drive is carried out with the injection speed of 0.8mL/min, until production fluid water ratio reaches 98%, calculate binary combination flooding ultimate recovery factor; Last with the three-phase froth flooding system solution of the certain volume of voids of injection speed alter least-squares of 0.1mL/min and gas, carry out water drive experiment with the injection speed of 0.8mL/min until production fluid water ratio terminates experiment after reaching 98%, calculate ultimate recovery factor.It is 0.15-0.25PV that described binary combination flooding oil systems solution and three-phase froth flooding system solution inject slug, gas inject slug is 0.15-0.5PV, the volume ratio of described gas and described three-phase forced foam flooding system solution is 1-3:1, and gas-liquid injection mode is repeatedly alternate injection.
The preparation of polymine jelly system
Preparation example 1
Be in the NaCl aqueous solution of 10000mg/L in 100g salinity, add 0.8g S-WAT, 0.6g molecular weight be 1,600 ten thousand anion-polyacrylamide, stir 2-3h under normal temperature to dissolve completely to anion-polyacrylamide, then add 0.3g molecular weight be 15000 linking agent polymine stir after namely obtain polymine jelly system.
Preparation example 2
Be in the NaCl aqueous solution of 10000mg/L in 100g salinity, add 0.6g thiocarbamide, 0.7g molecular weight be 1,600 ten thousand anion-polyacrylamide, stir 2-3h under normal temperature to dissolve completely to anion-polyacrylamide, then add 0.3g molecular weight be 15000 linking agent polymine stir after namely obtain polymine jelly system.
Core oil-displacement test is carried out to three-phase strengthening foam system according to the present invention below.
Embodiment 1
Be 1,600 ten thousand by 1g molecular weight, degree of hydrolysis be 10% polyacrylamide join in 200g deionized water, after stirring 10min is uniformly dissolved, add carbon nanotube and 1g polymine jelly system that 1g diameter is 20nm, stir 10min to be uniformly dispersed, then 1.2g sorbitan monooleate Soxylat A 25-7 is added and 1.2g fatty acid methyl ester ethoxylate stirs, make flooding system solution, it is 497mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 42min, and the surface tension of water-oil interface is 12.54 × 10
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 3:1.
Embodiment 2
Be 1,600 ten thousand by 2g molecular weight, degree of hydrolysis be 10% polyacrylamide join in 200g deionized water, after stirring 10min is uniformly dissolved, add nano silicon and 0.8g polymine jelly system that 1g diameter is 50nm, stir 10min to be uniformly dispersed, then 0.5g polyoxyethylene nonylphenol ether is added and 1.5g Sodium dodecylbenzene sulfonate stirs, make flooding system solution, it is 481mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 37min, and the surface tension of water-oil interface is 17.16 × 10
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 2:1.
Embodiment 3
By 2g molecular weight be 300,000 polyvinyl alcohol join in 200g deionized water, after stirring 10min is uniformly dissolved, add calcium carbonate and 0.6g polymine jelly system that 1g diameter is 25nm, stir 10min to be uniformly dispersed, then add 2g sorbitan monooleate Soxylat A 25-7 to stir, make flooding system solution, it is 469mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 31min, and the surface tension of water-oil interface is 25.58 × 10
-3mN/m.Carbon dioxide: flooding system solution injects rock core with the ratio of 1.2:1.
Embodiment 4
By 2g molecular weight be 300,000 polyvinyl alcohol and 2g molecular weight be 1,600 ten thousand, degree of hydrolysis be 10% polyacrylamide join in the deionized water of 200g, after stirring 10min is uniformly dissolved, add silicon-dioxide and 0.8g polymine jelly system that 1.2g diameter is 50nm, stir 10min to be uniformly dispersed, then 1g polyoxyethylene nonylphenol ether is added and 1g sorbitan monooleate Soxylat A 25-7 stirs, make flooding system solution, it is 526mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 48min, the surface tension of water-oil interface is 7.63 × 10
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 2:1.
Embodiment 5
Be 1,600 ten thousand by 1g molecular weight, degree of hydrolysis be 10% polyacrylamide join in 200g deionized water, after stirring 10min is uniformly dissolved, add titanium dioxide and 0.6g polymine jelly system that 1g diameter is 50nm, stir 10min to be uniformly dispersed, then add 1g sorbitan monooleate Soxylat A 25-7,1g fatty acid methyl ester ethoxylate stirs, make flooding system solution, it is 489mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 39min, and the surface tension of water-oil interface is 13.37 × 10
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 2.5:1.
Embodiment 6
By 3g molecular weight be 300,000 polyvinyl alcohol join in 200g deionized water, after stirring 10min is uniformly dissolved, add zinc oxide and 0.8g polymine jelly system that 2g diameter is 50nm, stir 10min to be uniformly dispersed, then 2g sorbitan monooleate Soxylat A 25-7 is added and 1g Sodium dodecylbenzene sulfonate stirs, make flooding system solution, it is 512mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 45min, and the surface tension of water-oil interface is 9.56 × 10
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 1.5:1.
Embodiment 7
By 2g molecular weight be 300,000 polyvinyl alcohol join in the deionized water of 200g, after stirring 10min is uniformly dissolved, add titanium dioxide and 1.0g polymine jelly system that 1g diameter is 50nm, stir 10min to be uniformly dispersed, then add 1g polyoxyethylene nonylphenol ether and 0.8g fatty acid methyl ester ethoxylate stirs, make flooding system solution, it is 475mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 33min, and the surface tension of water-oil interface is 21.76 × 10
-3mN/m.Air: flooding system solution injects rock core with the ratio of 2:1.
Embodiment 8
Be 1,600 ten thousand by 1g molecular weight, degree of hydrolysis be 10% polyacrylamide and 1g molecular weight be 300,000 polyvinyl alcohol join in 200g deionized water, after stirring 10min is uniformly dissolved, add nano-calcium carbonate and 1.2g polymine jelly system that 2g diameter is 50nm, stir 10min to be uniformly dispersed, then 1g polyoxyethylene nonylphenol ether is added and 2g sorbitan monooleate Soxylat A 25-7 stirs, make flooding system solution, it is 478mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 35min, the surface tension of water-oil interface is 18.26 × 10
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 1.6:1.
Comparative example 1
Be 1,600 ten thousand by 1g molecular weight, degree of hydrolysis be 10% polyacrylamide join in 200g deionized water, after stirring 10min is uniformly dissolved, add the carbon nanotube that 1g diameter is 20nm, stir 10min to be uniformly dispersed, then 1.2g sorbitan monooleate Soxylat A 25-7 is added and 1.2g fatty acid methyl ester ethoxylate stirs, make flooding system solution, it is 465mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period, the surface tension of water-oil interface was 35.57 × 10 in order to be 23min
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 3:1.
Comparative example 2
By 2g molecular weight be 300,000 polyvinyl alcohol join in 200g deionized water, after stirring 10min is uniformly dissolved, add 0.6g polymine jelly system, stir 10min to be uniformly dispersed, then add 2g sorbitan monooleate Soxylat A 25-7 to stir, make flooding system solution, it is 459mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 20min, and the surface tension of water-oil interface is 39.58 × 10
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 1.2:1.
Comparative example 3
By 1g molecular weight be 300,000 polyvinyl alcohol join in 200g deionized water, after stirring 10min is uniformly dissolved, add 2g sorbitan monooleate Soxylat A 25-7 and 1g Sodium dodecylbenzene sulfonate stirs, make flooding system solution, it is 449mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 15min, and the surface tension of water-oil interface is 45.63 × 10
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 1.5:1.
Comparative example 4
Be 1,600 ten thousand by 1g molecular weight, degree of hydrolysis be 10% polyacrylamide join in 200g deionized water, after stirring 10min is uniformly dissolved, add 1g tetradecyl hydroxy sulfo lycine and 1g diameter is the nano silicon of 50nm, stir, make flooding system solution, it be 453mL and transformation period is 16min that laboratory experiment records the lather volume produced at 70 DEG C, and the surface tension of water-oil interface is 42.68 × 10
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 1:1.
Comparative example 5
Be 1,600 ten thousand by 1g molecular weight, degree of hydrolysis be 10% polyacrylamide join in 200g deionized water, after stirring 10min is uniformly dissolved, add 1g tetradecyl hydroxy sulfo lycine and 1g novalac polymer frozen glue dispersion, stir, make flooding system solution, it be 455mL and transformation period is 18min that laboratory experiment records the lather volume produced at 70 DEG C, and the surface tension of water-oil interface is 40.64 × 10
-3mN/m.According to nitrogen: flooding system solution injects rock core with the ratio of 1:1.
Comparative example 6
Be 1,600 ten thousand by 2g molecular weight, degree of hydrolysis be 10% polyacrylamide join in 200g deionized water, after stirring 10min is uniformly dissolved, add 0.5g novalac polymer frozen glue dispersion, stir 10min to be uniformly dispersed, then add 1g polyoxyethylene nonylphenol ether to stir, make flooding system solution, it is 463mL that laboratory experiment records the lather volume produced at 70 DEG C, transformation period is 21min, and the surface tension of water-oil interface is 37.17 × 10
-3mN/m.Nitrogen: flooding system solution injects rock core with the ratio of 1.5:1.
As can be seen from embodiment 1-8, three-phase forced foam flooding system prepared by the present invention all can obtain more satisfactory stable foam, the transformation period of foam is all greater than 30min, and significantly can reduce the surface tension of water-oil interface, and water-oil interface surface tension can be reduced to 26 × 10
-3below the mN/m order of magnitude.
Table 1 core oil-displacement test result
As can be seen from Table 1, three-phase forced foam flooding system prepared in accordance with the present invention, can significantly improve the oil recovery factor after binary combination flooding.Adopting described three-phase forced foam flooding system to carry out, the ultimate recovery factor of displacement test is maximum on the basis of binary combination flooding improves 35.58%, ultimate recovery factor is the highest can reach 86.64%, compare with comparative example, no matter from total recovery ratio, or all have from recovery ratio increased value aspect and significantly improve, the three-phase forced foam flooding system that thus prepared by the present invention has better development effectiveness to improving oil recovery after binary combination flooding further.
Claims (8)
1. a three-phase forced foam flooding system after binary combination flooding, by liquid phase, the gentle phase composite of solid phase, wherein, liquid phase is made up of pore forming material, suds-stabilizing agent and water; Solid phase is made up of polymine jelly system and inorganic nano material; Gas phase is selected from nitrogen, air or carbonic acid gas.
The consumption of described pore forming material is the 0.05-5% of liquid phase quality; The consumption of described suds-stabilizing agent is the 0.1-3% of liquid phase quality; The consumption of described inorganic nano material is the 0.2-3% of liquid phase quality; The consumption of described polymine jelly system is the 0.05-1% of liquid phase quality; The volume ratio of gas phase and liquid phase is 1-3:1.
2. three-phase forced foam flooding system after binary combination flooding according to claim 1, wherein, pore forming material is selected from one or more in polyoxyethylene nonylphenol ether, sorbitan monooleate Soxylat A 25-7, fatty acid methyl ester ethoxylate, Sodium dodecylbenzene sulfonate.
3. three-phase forced foam flooding system after binary combination flooding according to claim 1, wherein, described suds-stabilizing agent be selected from polyacrylamide and polyvinyl alcohol one or more.
4. three-phase forced foam flooding system after binary combination flooding according to claim 3, wherein, the molecular weight of described polyacrylamide is 1000-2000 ten thousand, and degree of hydrolysis is 5-15%; The molecular weight of polyvinyl alcohol is 20-40 ten thousand.
5. three-phase forced foam flooding system after binary combination flooding according to claim 1, wherein, described inorganic nano material is selected from carbon nanotube, nano zine oxide, nano silicon, nano titanium oxide or nano-calcium carbonate; Described inorganic nano material is of a size of 20-50nm.
6. three-phase forced foam flooding system after binary combination flooding according to claim 1, wherein, polymine jelly system is reacted by partially hydrolyzed polyacrylamide and linking agent polymine and is formed, by percentage to the quality, polymine jelly system comprises following component: partially hydrolyzed polyacrylamide 0.1 ~ 0.8%, linking agent polymine 0.1 ~ 0.6%, additive 0.2 ~ 1%, surplus is water.
7. three-phase forced foam flooding system after binary combination flooding according to claim 1, wherein, described pore forming material is sorbitan monooleate Soxylat A 25-7 and fatty acid methyl ester ethoxylate; Described suds-stabilizing agent is polyacrylamide; Solid phase is made up of carbon nanotube and polymine jelly system, and gas phase is nitrogen.
8. three-phase forced foam flooding system after binary combination flooding according to claim 1, wherein, described pore forming material is polyoxyethylene nonylphenol ether and sorbitan monooleate Soxylat A 25-7; Described suds-stabilizing agent is polyvinyl alcohol and polyacrylamide; Solid phase is made up of polymine jelly system and nano silicon, and gas phase is nitrogen.
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Cited By (5)
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| CN111849449A (en) * | 2020-06-28 | 2020-10-30 | 中国石油大学(北京) | Supercritical CO2Oil displacement system and oil displacement method |
| CN112094632A (en) * | 2020-10-21 | 2020-12-18 | 西南石油大学 | Nano harm-removing agent and preparation method thereof |
| CN114989796A (en) * | 2021-03-02 | 2022-09-02 | 中国石油天然气股份有限公司 | Gas channeling prevention system and application thereof |
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| CN103980873A (en) * | 2014-06-04 | 2014-08-13 | 中国地质大学（北京） | Three-phase foam complex oil flooding system and application thereof |
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| CN111849449A (en) * | 2020-06-28 | 2020-10-30 | 中国石油大学(北京) | Supercritical CO2Oil displacement system and oil displacement method |
| CN112094632A (en) * | 2020-10-21 | 2020-12-18 | 西南石油大学 | Nano harm-removing agent and preparation method thereof |
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