CN102562012A - Method for improving recovery ratio of normal heavy oil reservoirs in water-flooding development - Google Patents
Method for improving recovery ratio of normal heavy oil reservoirs in water-flooding development Download PDFInfo
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- CN102562012A CN102562012A CN2010106222591A CN201010622259A CN102562012A CN 102562012 A CN102562012 A CN 102562012A CN 2010106222591 A CN2010106222591 A CN 2010106222591A CN 201010622259 A CN201010622259 A CN 201010622259A CN 102562012 A CN102562012 A CN 102562012A
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Abstract
The invention discloses a method for improving the recovery ratio of normal heavy oil reservoirs in water-flooding development, comprising the steps of (1) preparing microgel and water to be 1000-3000mg/l of solution; (2), preparing surfactants and water to be 2000-3000mg/l of solution; and (3), filling a microgel solution slug and a surfactant solution slug from a water well, wherein the microgel is copolymer of acrylic amide and methylene diacrylamide; the surfactant is alkylbenzene sulfonate surfactant. In the invention, based on the characteristic of strong anisotropy of the water-flooding developed reservoirs, the method fully uses a movable microgel profile control action mechanism and a surfactant oil-displacing action mechanism in a composite system through a filled composite microgel profile control system, so that the method can improve the anisotropy in reservoir stratums and among reservoir stratums, solve a fingering condition, increase water-displacing waves and volumes and improve the displacement efficiency, thereby drastically improving the oil recovery; indoor core tests show that the total recovery ratio is up to 80-90%.
Description
Technical field
The invention belongs to oil recovery field, oil field, particularly a kind of method that improves water drive exploitation common heavy oil reservoir recovery ratio.
Background technology
The common heavy oil reservoir of water drive exploitation because in the ubiquity layer, the strong non-homogeneity of interlayer, the high characteristics of viscosity ratio of oil and water, make reservoir waterflooding have serious tonguing, fingering phenomenon.After the oil field got into development late stage, tonguing, fingering phenomenon were more obvious, have a strong impact on the raising of crude oil recovery percent of reserves.
Around how improving such reservoir development effect, increase this problem of recoverable reserves, during many for many years experts are making great efforts to inquire into always.People such as Du Yuhong (Du Yuhong, Wu Hangcai, Chen Hong; Ceng Qingqiao, the movable application of gel profile control technology in common heavy oil reservoir, Southwest Petrol University's journal; 2008; 30 (3)) once proposed the method that movable gel profile control technology is improved water drive exploitation common heavy oil reservoir development effectiveness in 2008, this technology adopts polymer to add the chromium cross-linking agent carboxylate and is mixed with movable gel rubber system, adopts skid-mounted type injection technology flow process to carry out the mining site construction.See the advantage that this method has section adjustment, fluid diversion and improves aspects such as oil-displacement capacity from laboratory experiment and field test result.
In realizing process of the present invention; The inventor finds that there is following problem at least in prior art: the field test shortcoming: the one, and movable gel profile control technology adopts polymer and crosslinking agent to inject underground in certain sequence; Thereby make the two carry out shutoff to high aquifer,, therefore become glue reliability, poor controllability because system need be underground crosslinked underground crosslinked; Mining site exists system not become the glue phenomenon underground, has influenced raising recovery ratio effect greatly; The 2nd, the movable gel rubber system viscosity of injecting is too high, is difficult to advance into the purpose that the reservoir depths reaches reservoir deep fluid diversion, and treatment radius is too small, and it is limited to improve the recovery ratio amplitude.
Summary of the invention
The purpose of the embodiment of the invention is the defective to above-mentioned prior art, and a kind of method is provided, and this method can be improved in the reservoir layer, interlayer heterogeneity, solves tonguing, fingering phenomenon, thereby improves water drive exploitation common heavy oil reservoir recovery ratio.
The technical scheme taked of the present invention is to achieve these goals: a kind of method that improves water drive exploitation common heavy oil reservoir recovery ratio may further comprise the steps:
(1) microgel and water are configured to concentration 1000-3000mg/l solution;
(2) surfactant and water are configured to concentration 2000-3000mg/l solution;
(3) inject microgel solution slug and surfactant solution slug from well;
Said microgel is acrylamide and methylene diacrylamide copolymer;
Said surfactant is an alkyl benzene sulfonate surfactant.
Described microgel solution slug injection rate is 0.18 times of oil reservoir voids volume.
Described surfactant slug injection rate is 0.02 times of oil reservoir voids volume.
Optimized technical scheme of the present invention: improve the method for water drive exploitation common heavy oil reservoir recovery ratio, may further comprise the steps:
(1) microgel and water are configured to concentration 1000-3000mg/l solution;
(2) surfactant and water are configured to concentration 2000-3000mg/l solution;
(3) from well, inject following slug successively: inject 0.08 times of movable microgel of oil reservoir voids volume submillimeter level, the movable microgel diameter d of said submillimeter level is 10-100 μ m, concentration 1000-3000mg/l; 0.1 the movable microgel of oil reservoir voids volume micron order doubly, the movable microgel diameter d of said micron order is 1-5 μ m, concentration 1000-3000mg/l; 0.02 oil reservoir voids volume surfactant doubly, said surfactant concentration is 2000-3000mg/l.
The preferred technical scheme of the present invention: improve the method for water drive exploitation common heavy oil reservoir recovery ratio, may further comprise the steps:
(1) at first the movable microgel of submillimeter level is pumped into waterflood-transmission line, be configured to the preposition shutoff slug of concentration 1000-3000mg/l, injection rate is 0.08 times of voids volume.
(2) according to 4: 1 ratios movable microgel of micron order and surfactant mixing are pumped into waterflood-transmission line then, be configured to the transfer drive principal piece plug of concentration 2000mg/l, injection rate is 0.1 times of voids volume.
(3) at last the movable microgel of submillimeter level is pumped into waterflood-transmission line, the postposition that is configured to concentration 1000mg/l is sealed slug, and injection rate is 0.02 times of voids volume.
Described microgel slug and surfactant slug and follow-up water drive slug are periodically alternately to inject, and the injection cycle is 30-100 days.
The beneficial effect that the technical scheme that the embodiment of the invention provides is brought is:
The present invention is based on the strong characteristics of water drive exploitation oil reservoir non-homogeneity; Through injecting composite microgel transfer drive system, give full play to the movable microgel profile control mechanism of action and the surfactant flooding mechanism of action in the compound system, can improve that the reservoir layer is interior, interlayer heterogeneity; Solve tonguing, fingering phenomenon; When increasing the water drive swept volume, improved displacement efficiency again, thereby increased substantially oil recovery factor, the laboratory core experiment shows that overall recovery factor can be up to 80-90%.
The present invention has following outstanding feature:
1. between composite microgel transfer drive system influx time, can obviously increase the swept volume and the oil displacement efficiency of displacing fluid.
(1) microgel in the composite microgel transfer drive system is the elasticity orbicule, can block up height temporarily and ooze passage, make displacing fluid turn in hypotonic position, the oil reservoir vertical profile becomes more even, all directions displacement velocity is bordering on unanimity on the plane, thereby has enlarged swept volume.
(2) alkyl benzene sulfonate surfactant in the composite microgel transfer drive system can reduce oil water interfacial tension significantly, reduces the crude oil flow resistance, thereby has improved oil displacement efficiency.
2. in the follow-up water drive stage after composite microgel transfer drive system is injected,, make further to have enlarged water drive swept volume and oil displacement efficiency in the follow-up water drive process because compound transfer drive system lowered water phase permeability, reduced the crude oil flow resistance.
Recovery ratio can improve 10-40% after the artificial core experiment of the embodiment of the invention showed the compound transfer drive system of injection microgel, and overall recovery factor reaches 80-90%.
Certain Cut of Oilfield 96.8%, recovery percent of reserves 43.2% are injected test well group water cut decreases to 90% after the compound transfer drive system, and a day produce oil is increased to 8.5t/d by 2.9t/d, has obtained better effects.
The present invention can develop common heavy oil reservoir and ligh-oil reservoir development late stage in water drive, and further improving oil recovery factor for the oil field provides a kind of new effective method, is applicable to that reservoir temperature is not higher than 120 ℃; Preferred 0-120 ℃; Formation water salinity is no more than 180000mg/l, preferred 0-180000mg/l, and the underground viscosity of crude oil is lower than 150mP.s; Preferred 0-150mP.s, permeability 200 * 10
-3μ m
2-3000 * 10
-3μ m
2Oil reservoir.
Description of drawings
Fig. 1 is the dynamic displacement of reservoir oil curve of filling the artificial core of sandpipe according to the non-average that provides in the embodiment of the invention 1;
Fig. 2 is the dynamic displacement of reservoir oil curve of filling the artificial core of sandpipe according to the non-average that provides in the embodiment of the invention 2.
The specific embodiment
For making the object of the invention, technical scheme and advantage clearer, will combine accompanying drawing that embodiment of the present invention is done to describe in detail further below.
Embodiment 1: the artificial fill out sand tube rock core of the non-average of composite microgel transfer drive system oil displacement experiment
Experiment condition:
The artificial fill out sand tube parallel connection of non-average rock core: permeability is respectively 3370md, 480md.
Experiment is with oily: take from the degassing dewatered oil in 1 in sea, Liaohe Oil Field, its viscosity is 75.0mPa s under 70 ℃.
Experimental water: take from the Simulated Water of Liaohe Oil Field sea 4 station dosings with sewage, salinity is 2286.5mg/L
The movable microgel of compound profile control agent: 1000mg/l (product that stone big ten thousand good energy and environment science and technology limited Company in Beijing are produced), 3000mg/l neopelex surfactant (U.S. ORS of SCI company series of products) mix compound system.
Experimental temperature: 70 ℃
Experimental procedure:
(1) physical model was found time 4-5 hour, the saturation simulation formation water is measured voids volume then;
(2) rock core of saturated brine is put in the insulating box, 70 ℃ of following constant temperature 16 hours;
(3) physical model is surveyed permeability Kw with simulated formation water down for 70 ℃;
(4) saturated oils: vertically put physical model well, oily from top to bottom expelling water, rock core export not till the water breakthrough, calculate initial oil saturation and irreducible water saturation;
(5) water drive oil: with moisture 98% o'clock end water drive oil, the calculating waterflood recovery efficiency factor of reaching of displacement velocity water drive oil to the rock core outlet of 1.5ml/min;
(6) annotate compound transfer drive system: inject the 0.08 times of movable microgel of voids volume submillimeter level (microgel diameter d=10-100 μ m with the speed identical with water drive oil; Concentration 1000mg/l), 0.1 times of movable microgel of voids volume micron order (microgel diameter d=1-5 μ m, concentration 1000mg/l), 0.02 times of voids volume surfactant (concentration 3000mg/l).
(7) with moisture end in 98% o'clock, calculating transfer drive recovery ratio and the ultimate recovery of reaching of displacement velocity later stage water drive to the rock core outlet identical with water drive oil.
Experimental result:
Referring to Fig. 1, experimental result shows: can on the water drive basis, increase recovery ratio 30.05% after injecting compound transfer drive system, overall recovery factor 53.82% during by water drive brings up to 83.87%.
Embodiment 2: the artificial fill out sand tube rock core of the non-average of composite microgel transfer drive system oil displacement experiment
Experiment condition:
The artificial fill out sand tube parallel connection of non-average rock core: permeability is respectively 2810md, 510md.
Experiment is with oily: take from the degassing dewatered oil in 1 in sea, Liaohe Oil Field, its viscosity is 75.0mPa s under 70 ℃.
Experimental water: take from the Simulated Water of Liaohe Oil Field sea 4 station dosings with sewage, salinity is 2286.5mg/L
The movable microgel of compound profile control agent: 1000mg/l (product that stone big ten thousand good energy and environment science and technology limited Company in Beijing are produced), 3000mg/l DBSA ammonium surfactant (U.S. ORS of SCI company series of products) mix compound system.
Experimental temperature: 70 ℃
Experimental procedure:
(1) physical model was found time 4-5 hour, the saturation simulation formation water is measured voids volume then;
(2) rock core of saturated brine is put in the insulating box, 70 ℃ of following constant temperature 16 hours;
(3) physical model is surveyed permeability Kw with simulated formation water down for 70 ℃;
(4) saturated oils: vertically put physical model well, oily from top to bottom expelling water, rock core export not till the water breakthrough, calculate initial oil saturation and irreducible water saturation;
(5) water drive oil: with moisture 98% o'clock end water drive oil, the calculating waterflood recovery efficiency factor of reaching of displacement velocity water drive oil to the rock core outlet of 1.5ml/min;
(6) annotate compound transfer drive system: inject the 0.08 times of movable microgel of voids volume submillimeter level (microgel diameter d=10-100 μ m with the speed identical with water drive oil; Concentration 3000mg/l), 0.1 times of movable microgel of voids volume micron order (microgel diameter d=1-5 μ m, concentration 3000mg/l), 0.02 times of voids volume surfactant (concentration 3000mg/l).
(7) with moisture end in 98% o'clock, calculating transfer drive recovery ratio and the ultimate recovery of reaching of displacement velocity later stage water drive to the rock core outlet identical with water drive oil.
Experimental result:
Referring to Fig. 2, experimental result shows: after the concentration of microgel was increased to 3000mg/l from 1000mg/l in the compound transfer drive system, the recovery ratio increase rate slightly increased.Injecting increases recovery ratio 39.35% after the compound transfer drive system on the water drive basis, overall recovery factor 51.57% during by water drive brings up to 90.92%.It can also be seen that from experimental result picture; Injecting after the compound transfer drive system pressure curve raises and has wave phenomenon; Show that compound transfer drive system has played the effect of temporary transient shutoff high permeability formation, compound transfer drive system breakthrough pore throat migrates to next pore throat place, place and produces shutoff after pressure is higher than breakthrough pressure.Pressure decreases but still pressure when being higher than original water drive after the follow-up water drive.
Embodiment 3: composite microgel transfer drive system mining site is implemented
(1) at first the movable microgel of submillimeter level is pumped into waterflood-transmission line through pump for well, be configured to the preposition shutoff slug of concentration 1000mg/l, injection rate is 0.08 times of oil reservoir voids volume.
(2) according to 4: 1 ratios the movable microgel of micron order and surfactant are mixed then after, pump into waterflood-transmission line through pump for well, be configured to the transfer drive principal piece plug of concentration 2000mg/l, injection rate is 0.1 times of oil reservoir voids volume.
(3) at last the movable microgel of submillimeter level is pumped into waterflood-transmission line through pump for well, the postposition that is configured to concentration 1000mg/l is sealed slug, and injection rate is 0.02 times of oil reservoir voids volume.
Microgel in the present embodiment is acrylamide and methylene diacrylamide copolymer, promptly movable microgel; Surfactant is a neopelex.
In order to reach better recovery ratio, the microgel slug of above-mentioned steps of the present invention and surfactant slug and follow-up water drive slug are periodically alternately to inject, and the injection cycle is 30 days, and promptly above-mentioned steps needs whenever to implement once at a distance from 30 days.
Embodiment 4: the method that improves water drive exploitation common heavy oil reservoir recovery ratio
(1) reaches moisture content 90% when above when water drive; At first the movable microgel of submillimeter level is pumped into waterflood-transmission line through pump for well; Movable microgel diameter d is 10-100 μ m, is configured to the preposition shutoff slug of concentration 2000mg/l, and injection rate is 0.08 times of voids volume.
(2) the more movable microgel of micron order is pumped into waterflood-transmission line through pump for well, the movable microgel diameter d of micron order is 1-5 μ m, is configured to the transfer drive principal piece plug of concentration 1000mg/l, and injection rate is 0.1 times of oil reservoir voids volume.
(3) at last surfactant is pumped into waterflood-transmission line through pump for well, the postposition that is configured to concentration 3000mg/l is sealed slug, and injection rate is 0.02 times of oil reservoir voids volume.
Microgel in the present embodiment is acrylamide and methylene diacrylamide copolymer, promptly movable microgel; Surfactant is the DBSA ammonium.
In order to reach better recovery ratio, the microgel slug of above-mentioned steps of the present invention and surfactant slug and follow-up water drive slug are periodically alternately to inject, and the injection cycle is 100 days, and promptly above-mentioned steps needs whenever to implement once at a distance from 100 days.
The transfer drive system that the present invention adopts is a kind of functional form acrylamide copolymer-movable microgel and alkyl benzene sulfonate surfactant compound system.Wherein the Main Ingredients and Appearance of functional form acrylamide copolymer is acrylamide and methylene diacrylamide, and movable microgel is the acrylamide and the methylene diacrylamide copolymer of a series of grafting, block.Movable microgel itself both can be used as profile control agent and also can be used as oil displacement agent.The movable microgel that the present invention adopts is used for profile control and does the time spent, and microgel is not that macropore is blocked, but temporarily hinders the migration of fluid in the macropore, makes fluid in interlayer, layer, flow in the lower low-permeability layer of osmotic resistance, thereby enlarges swept volume.Microgel is piled up macropore plugging through building bridge at interstitial space makes follow-up water stream, when the rising of shutoff build-up of pressure, when pressure reduction is elevated to a certain degree; Elastic deformation can take place again in microgel; Through pore constriction, continue to the migration of reservoir deep, the place produces temporary transient shutoff at the big venturi of the next one; Therefore microgel is a migration, shutoff, distortion in reservoir pore space through, migration again, the so reciprocal continuous process of shutoff again; Thereby on three dimensions, constantly the fluid in the reservoir is flowed to adjustment, effectively enlarged swept volume, improved recovery ratio.
The above is merely preferred embodiment of the present invention, and is in order to restriction the present invention, not all within spirit of the present invention and principle, any modification of being done, is equal to replacement, improvement etc., all should be included within protection scope of the present invention.
Claims (8)
1. a method that improves water drive exploitation common heavy oil reservoir recovery ratio is characterized in that, may further comprise the steps:
(1) microgel and water are configured to concentration 1000-3000mg/l solution;
(2) surfactant and water are configured to concentration 2000-3000mg/l solution;
(3) inject microgel solution slug and surfactant solution slug from well;
Said microgel is acrylamide and methylene diacrylamide copolymer;
Said surfactant is an alkyl benzene sulfonate surfactant.
2. the method for raising water drive exploitation common heavy oil reservoir recovery ratio according to claim 1, it is characterized in that: described microgel solution slug injection rate is 0.18 times of oil reservoir voids volume.
3. the method for raising water drive exploitation common heavy oil reservoir recovery ratio according to claim 1, it is characterized in that: described surfactant slug injection rate is 0.02 times of oil reservoir voids volume.
4. the method for raising water drive exploitation common heavy oil reservoir recovery ratio according to claim 1 is characterized in that, may further comprise the steps:
Said step (3) is: from well, inject following slug successively: inject 0.08 times of movable microgel of oil reservoir voids volume submillimeter level, the movable microgel diameter d of said submillimeter level is 10-100 μ m, concentration 1000-3000mg/l; 0.1 the movable microgel of oil reservoir voids volume micron order doubly, the movable microgel diameter d of said micron order is 1-5 μ m, concentration 1000-3000mg/l; 0.02 oil reservoir voids volume surfactant doubly, said surfactant concentration is 2000-3000mg/l.
5. the method for raising water drive exploitation common heavy oil reservoir recovery ratio according to claim 1 is characterized in that, may further comprise the steps:
(1) at first the movable microgel of submillimeter level is pumped into waterflood-transmission line, be configured to the preposition shutoff slug of concentration 1000-3000mg/l, injection rate is 0.08 times of voids volume;
(2) according to 4: 1 ratios movable microgel of micron order and surfactant mixing are pumped into waterflood-transmission line then, be configured to the transfer drive principal piece plug of concentration 2000mg/l, injection rate is 0.1 times of voids volume;
(3) at last the movable microgel of submillimeter level is pumped into waterflood-transmission line, the postposition that is configured to concentration 1000mg/l is sealed slug, and injection rate is 0.02 times of voids volume.
6. the method for raising water drive exploitation common heavy oil reservoir recovery ratio according to claim 1, it is characterized in that: described microgel slug and surfactant slug and follow-up water drive slug are for periodically alternately injecting, and the injection cycle is 30-100 days.
7. the method for raising water drive exploitation common heavy oil reservoir recovery ratio according to claim 1, it is characterized in that: said alkylbenzenesulfonate is neopelex or DBSA ammonium.
8. according to the method for each described raising water drive exploitation common heavy oil reservoir recovery ratio of claim 1-7, it is characterized in that:
Said method is applicable to reservoir temperature 0-120 ℃, formation water salinity 0-180000mg/l, the underground viscosity 0-150mP.s of crude oil, permeability 200 * 10
-3μ m
2-3000 * 10
-3μ m
2Oil reservoir.
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| CN104329082A (en) * | 2014-10-24 | 2015-02-04 | 中国海洋石油总公司 | Method for determining high-permeability thick-oil oil reservoir polymer flooding early stage polymer injection transfer occasion |
| CN104929597A (en) * | 2015-06-10 | 2015-09-23 | 中国石油天然气股份有限公司 | Horizontal well chemical flooding mining method |
| CN107218021A (en) * | 2017-08-06 | 2017-09-29 | 大庆东油睿佳石油科技有限公司 | A kind of double slug type profile control agents of Fracture with low permeability oil reservoir and its application method |
| CN107312515A (en) * | 2017-06-01 | 2017-11-03 | 大庆华理生物技术有限公司 | A kind of multi-element biologic compound oil displacement agent system and its injection technology |
| CN109899044A (en) * | 2019-03-26 | 2019-06-18 | 北京勃兴石油科技有限公司 | A kind of method that transfer drive washes alternately injection raising oil recovery factor |
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| CN110905460A (en) * | 2019-12-02 | 2020-03-24 | 中国石油化工股份有限公司 | Viscosity-reducing foaming exploitation method for common heavy oil reservoir |
| CN111734367A (en) * | 2020-06-28 | 2020-10-02 | 四川光亚聚合物化工有限公司 | Heterogeneous oil displacement method for preventing damage of permeable horizon |
| CN112943192A (en) * | 2021-02-03 | 2021-06-11 | 中国石油天然气股份有限公司 | Mining method suitable for low-permeability conglomerate oil reservoir |
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| CN115142824A (en) * | 2021-03-31 | 2022-10-04 | 中国石油天然气股份有限公司 | Chemical flooding oil production method |
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| CN104329082A (en) * | 2014-10-24 | 2015-02-04 | 中国海洋石油总公司 | Method for determining high-permeability thick-oil oil reservoir polymer flooding early stage polymer injection transfer occasion |
| CN104929597A (en) * | 2015-06-10 | 2015-09-23 | 中国石油天然气股份有限公司 | Horizontal well chemical flooding mining method |
| CN107312515A (en) * | 2017-06-01 | 2017-11-03 | 大庆华理生物技术有限公司 | A kind of multi-element biologic compound oil displacement agent system and its injection technology |
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| CN109915093B (en) * | 2019-03-28 | 2021-01-26 | 东北石油大学 | Method for improving oil reservoir recovery ratio by integrating' plugging/regulating/flooding |
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| CN110905460A (en) * | 2019-12-02 | 2020-03-24 | 中国石油化工股份有限公司 | Viscosity-reducing foaming exploitation method for common heavy oil reservoir |
| CN110905460B (en) * | 2019-12-02 | 2021-08-20 | 中国石油化工股份有限公司 | Viscosity-reducing foaming exploitation method for common heavy oil reservoir |
| CN111734367A (en) * | 2020-06-28 | 2020-10-02 | 四川光亚聚合物化工有限公司 | Heterogeneous oil displacement method for preventing damage of permeable horizon |
| CN111734367B (en) * | 2020-06-28 | 2022-06-21 | 四川光亚聚合物化工有限公司 | Heterogeneous oil displacement method for preventing damage of permeable horizon |
| CN114645690A (en) * | 2020-12-21 | 2022-06-21 | 中国石油化工股份有限公司 | Composite profile control and flooding process for gel dispersion |
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| CN115142824A (en) * | 2021-03-31 | 2022-10-04 | 中国石油天然气股份有限公司 | Chemical flooding oil production method |
| CN115142824B (en) * | 2021-03-31 | 2024-03-26 | 中国石油天然气股份有限公司 | Chemical flooding oil extraction method |
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