CN102650206A - Method for improving recovery ratio of non-homogeneous pay - Google Patents
Method for improving recovery ratio of non-homogeneous pay Download PDFInfo
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- CN102650206A CN102650206A CN2012101242511A CN201210124251A CN102650206A CN 102650206 A CN102650206 A CN 102650206A CN 2012101242511 A CN2012101242511 A CN 2012101242511A CN 201210124251 A CN201210124251 A CN 201210124251A CN 102650206 A CN102650206 A CN 102650206A
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Abstract
The invention relates to a method for improving the recovery ratio of a non-homogeneous pay. The method is a method for alternately injecting a foam slug and an alkali and surfactant binary solution slug to improve the recovery ratio of the non-homogeneous pay, and comprises the following steps: injecting the foam slug into an oil layer; and then injecting the alkali and surfactant binary solution slug to complete one injection period, wherein the total injection amount of the foam slug is 60 percent to 100 percent of the total pore volume of the oil layer, the total injection amount of the alkali and surfactant binary solution slug is 20 percent to 40 percent of the total pore volume of the oil layer and the one to four injection periods are carried out. The method for improving the recovery ratio of the non-homogeneous pay, which is provided by the invention, is low in cost, has obvious effect of improving the recovery ratio, can obtain good economic benefits and has wide application prospect.
Description
Technical field
The present invention relates to a kind of method that improves oil recovery rate, relate in particular to a kind of method that improves the non-homogeneous pay recovery ratio, belong to the oilfield exploitation technical field.
Background technology
Polymer displacement of reservoir oil tech has obtained development rapidly at home; For example; The industrialization promotion of Daqing oil field polymer displacement of reservoir oil is used and has been obtained the remarkable economical effect; Improve recovery ratio about 10% than water drive oil, yearly rate-oil production has been broken through ten million ton at present, becomes the great technical measures of oil field sustainable development.
However, still remain crude oil about 40-50% behind the polymer displacement of reservoir oil in the oil reservoir not by extraction, how further improving recovery ratio behind the polymer displacement of reservoir oil is present research focus.According to experimental study, ternary composite oil-displacing generally improves about 10% than gathering oil-recovering rate.Foam compsoite oil drive is on the basis of ternary composite driving, to grow up, and generally improves recovery ratio about 20% than polymer displacement of reservoir oil.The microbe oil production technology can improve recovery ratio about 5% behind the polymer displacement of reservoir oil.Ternary composite oil-displacing and foam compsoite oil drive effect are better, but cost is higher, and foam compsoite oil drive because injection pressure is high, receives the restriction of formation fracture pressure directly to stratum injection foam the time, can not continue to inject, and applies being restricted.And microbial oil displacement is because technological more complicated, and technology is not mature enough, temporarily is difficult to apply.
Therefore, the method for a kind of raising oil recovery rate new, that be suitable for practical application of exploitation is one of this area problem demanding prompt solution.
Summary of the invention
For solving the problems of the technologies described above; The object of the present invention is to provide a kind of method that can after polymer displacement of reservoir oil, improve reservoir recovery; Through adopting the mode of alternately injecting to realize improving the purpose of reservoir recovery; Simultaneously, this method also has the characteristics that composition is low, good in economic efficiency, application prospect is good.
For achieving the above object, the present invention at first provides a kind of method that improves the non-homogeneous pay recovery ratio, and it is to replace with foam slug, alkali and surfactant binary solution slug to inject the method that improves the non-homogeneous pay recovery ratio, may further comprise the steps:
Above-mentioned alternately the injection carried out 1-4 injection cycle; Wherein, Inject the foam slug to oil reservoir, and then inject alkali and surfactant binary solution slug is an injection cycle, the injection total amount of foam slug is the 60%-100% of oil reservoir total pore size volume; The injection total amount of alkali and surfactant binary solution slug is the 30%-60% of oil reservoir total pore size volume; And the injection rate of alkali and surfactant binary solution slug is 0.6mL/min, and the injection rate of foam slug is 1.2mL/min.
According to specific embodiments of the present invention; Preferably; To the stronger oil reservoir of non-homogeneity (coefficient of permeability variation); The injection overall control of foam slug is the 70-100% of oil reservoir total pore size volume, and the injection overall control of alkali and surfactant binary solution slug is the 40-60% of oil reservoir total pore size volume.
In said method provided by the present invention, preferably, the foam slug that is adopted is made up of gas and expanding foam solution, and wherein, expanding foam solution comprises first surface activating agent and polymer.
In said method provided by the present invention, preferably, expanding foam solution is the aqueous solution that contains first surface activating agent and polymer, and in this aqueous solution, the concentration of first surface activating agent is 0.1wt%, and the concentration of polymer is 200mg/L.
According to concrete technical scheme of the present invention, preferably, the first surface activating agent that is adopted in the expanding foam solution is an alpha-alkene sulfonate; Polymer is a partially hydrolyzed polyacrylamide (PHPA); The relative molecular weight of this partially hydrolyzed polyacrylamide (PHPA) is 1,500 ten thousand, and degree of hydrolysis is 24%, and solid content is more than 90%.
In said method provided by the present invention, preferably, the gas that is adopted is natural gas etc., and the volume ratio of gas and expanding foam solution is 1: 1.
In said method provided by the present invention, preferably, alkali and surfactant binary solution slug are the aqueous solution of alkali and surfactant; Wherein, In this aqueous solution, the concentration of alkali is 0.8-1.2wt%, and surfactant concentrations is 0.2-0.4wt% (being preferably 0.3wt%).According to concrete technical scheme of the present invention, preferably, the alkali in the above-mentioned binary solution slug is NaOH, and surfactant (second surface activating agent) is one or more in heavy alkylbenzene sulfonate, petroleum sulfonate and the betaine etc.
In said method provided by the present invention, preferably, the oil reservoir that alternately is infused in of foam slug, alkali and surfactant binary solution slug carries out carrying out after the polymer displacement of reservoir oil operation.According to concrete technical scheme of the present invention, preferably, method provided by the present invention can be carried out according to following concrete steps: oil reservoir is carried out the water drive oil operation, reach more than the 98v% until extraction liquid moisture content; Oil reservoir is carried out the polymer displacement of reservoir oil operation; Once more oil reservoir is carried out the water drive oil operation, reach more than the 98v% until extraction liquid moisture content; The foam slug, alkali and the surfactant binary solution slug that in oil reservoir, carry out 1-4 cycle alternately inject; The injection total amount of foam slug is the 60%-100% of oil reservoir total pore size volume; The injection total amount of alkali and surfactant binary solution slug is the 30%-60% of oil reservoir total pore size volume; The injection rate of alkali and surfactant binary solution slug is controlled to be 0.6mL/min, and the injection rate of foam slug is controlled to be 1.2mL/min.In above-mentioned steps, the polymer displacement of reservoir oil operation can be carried out according to the routine work mode in oil field.
In a preferred embodiment of the invention; The expanding foam solution that uses can be the binary solution of polyacrylamide and alpha-alkene sulfonate, and the foam performance of this expanding foam solution is good, but the interfacial tension performance is poor slightly; Polymer concentration in the expanding foam solution is lower, is used for stable foam.In oil reservoir, the foam slug can be brought into play the effect of mobility control and temporary transient macropore plugging, but can not reach ultralow interfacial tension, and washing oil is limited in one's ability.And alkali/surfactant binary solution slug can reach ultralow interfacial tension in the alkali concn of broad and surfactant concentration ranges, and displacement efficiency is very high, but the mobility control ability is relatively poor.Method provided by the present invention has reached better effect through foam and alkali/surfactant binary solution slug are used.Alkali/surfactant binary solution slug that foam injects the back has the mobility control effect and to the temporary transient plugging action of macropore; Make the alkali/surfactant binary solution that injects subsequently can get into the fine pore, give full play to the advantage that alkali/surfactant binary solution displacement efficiency is high, improve oil recovery factor; And the reduction of oil saturation helps the regeneration of foam and stable conversely in the hole; Thereby constantly enlarge swept volume, simultaneously, alkali/surfactant binary solution has certain foaming capacity concurrently; Make the gas in the foam be difficult for making breakthroughs, foam is had protective effect.
The method cost of raising non-homogeneous pay recovery ratio provided by the present invention is lower, and it is obvious to improve the recovery ratio effect, can obtain favorable economic benefit, has good application prospects.
Description of drawings
Fig. 1 is the normal pressure physical analogy displacement of reservoir oil device structure sketch map that embodiment adopted.
Main drawing reference numeral explanation:
1 constant-flux pump, 2 working fluid containers, 3 six-way valves, 4 pressure meters, 5 polymer solution jars
6 alkali/surfactant binary solution jar 7 injects water pot 8 foaming agent solution jars 9 rock cores
10 gatherers, 11 valves, 12 foam makers
The specific embodiment
To understand in order technical characterictic of the present invention, purpose and beneficial effect being had more clearly, technical scheme of the present invention is carried out following detailed description, but but can not be interpreted as qualification at present practical range of the present invention.
Present embodiment provides a kind of and has alternately injected the method that improves the non-homogeneous pay recovery ratio through foam, alkali/surfactant binary solution, wherein, simulates the oil reservoir situation with rock core.
One, experiment condition:
1, experiment material
Experiment is with oil---and Daqing oil field recovers the oil, and (paraffin content is 22%-25% to six factories multi-purpose station dehydration degassed crude, and gel content 17.9%, freezing point are 26.5 ℃, and in-place oil viscosity is 10.3mPas, and oil volume factor 1.118, initial gas-oil ratio are 48.0m
3/ t; The ground oil density is 0.88g/cm
3, the ground viscosity of crude is 22.9mPas);
Experimental water---the Daqing oil field six factory's return waters (belong to the sodium bicarbonate type, salinity is 5599mg/L, and chloride ion content is 992mg/L) that recover the oil;
Surfactant in chemical agent---alkali/surfactant binary solution slug is heavy alkylbenzene sulfonate (DQS), the surfactant in the expanding foam solution (alpha-alkene sulfonate); Alkali is NaOH; Polymer is partially hydrolyzed polyacrylamide (PHPA) (HPAM), and relative molecular mass is 1,500 ten thousand, and degree of hydrolysis is 24%, and solid content is 90%;
Experimental gas---artificial synthetic gas (natural gas);
Experimental temperature---45 ℃;
Experimental model---bidimensional vertical heterogeneity synthetic quartz sand epoxy gluing rock core, moulded dimension is 4.5 * 4.5 * 30cm, coefficient of permeability variation is respectively 0.6,0.72,0.8, no interlayer, the model perm-plug method is about 1 square micron.
2, the preparation of solution and simulated oil
The rock core saturation water is artificial synthetic salt solution, and salinity is 6778mg/L; The water drive water is the Daqing oil field six factory's return waters that recover the oil; Foaming agent solution is the binary solution of HPAM and alpha-alkene sulfonate, and with the return water preparation, the concentration of alpha-alkene sulfonate is 0.1%, and the concentration of polymer solution is 200mg/L; Also with the return water preparation, alkali concn is 1.2% to alkali/surfactant binary solution, and surfactant concentration is 0.3%;
Polymer flooding solution is prepared with clear water, and polymer flooding oil solution compound concentration is 1000mg/L, considers the shear action of ground dosing apparatus, pipeline and borehole wall borehole, and the work viscosity of polymer solution in the stratum often is lower than ground viscosity.In order to simulate the influence of shear action to polymer solution viscosity and oil displacement efficiency, the viscosity of the polymer solution that the model displacement of reservoir oil is used should be near the stratum viscosity of working, and one of method is to carry out preshearing to cut, two be to reduce the used concentration of polyacrylamide of dosing.Adopt first method in this experiment, according to the anti-discharge opeing viscosity test of Daqing oil field polymer drive injection well result, the stratum of polymer solution work viscosity is approximately 15mPaS, thus the polymer solution preshearing is cut, and making its viscosity is 15mPaS; Simulated oil is prepared with six factories degassing dewatered oil and aviation kerosine in proportion, and making its viscosity in the time of 45 ℃ is 13.5mPaS.
3, experimental facilities and flow process
(1) experimental facilities
Experimental facilities is normal pressure physical analogy displacement of reservoir oil equipment, and is as shown in Figure 1.Except constant-flux pump and gas cylinder, other all in 45 ℃ of insulating boxs.
(2) concrete steps:
Water drive: the water drive of utilizing constant-flux pump 1 will inject water pot 7 replaces into that rock core 9 carries out the displacement of reservoir oil, and the extraction liquid that from rock core 9, flows out gets into gatherer 10; What working fluid container 2 the insides were adorned is kerosene, and it is the working solution of constant-flux pump 1, is used for solution and foam flooding are replaced the entering rock core, and six-way valve 3 is used for the conversion of displacement flow process, and pressure meter 4 is used to monitor the pressure of core entry end;
Gather and drive: utilize constant-flux pump 1 that the polymer solution displacement in the polymer solution jar 5 is advanced to carry out the displacement of reservoir oil in the rock core 9; The extraction liquid that from rock core 9, flows out gets into gatherer 10; And then the water drive of utilizing constant-flux pump 1 will inject water pot 7 replaces into that rock core 9 carries out the displacement of reservoir oil, and the extraction liquid that from rock core 9, flows out gets into gatherer 10;
Foam and alkali/surfactant binary solution replaces the displacement of reservoir oil: utilize constant-flux pump 1 that the foaming agent solution displacement in the foaming agent solution jar 8 (switchings of these foaming agent solution jars 8 of valve 11 control) is advanced in the foam maker 12, mixes with gas form foam after injection rock core 9 carry out the displacement of reservoir oil; Then; Utilize constant-flux pump 1 that the alkali in alkali/surfactant binary solution jar 6/surfactant binary solution displacement is advanced to carry out the displacement of reservoir oil in the rock core 9; At last; The water drive of utilizing constant-flux pump 1 will inject water pot 7 again replaces into that rock core 9 carries out the displacement of reservoir oil, and the extraction liquid that from rock core 9, flows out gets into gatherer 10.
Two, experimental program:
1, water drive scheme:
1. the rock core model was vacuumized 4 hours, saturated then salinity is the salt solution of 6778mg/L, measures the degree of porosity of rock core;
2. the constant temperature that under 45 ℃, the rock core model was carried out 12 hours is handled;
3. utilize water to detect the permeability of rock core model;
4. to rock core model saturated oils, till oily under the same conditions then expelling water to rock core model exports not water outlet;
5. the extraction liquid moisture content that the rock core model is carried out water drive oil to rock core model outlet reaches till the 98v%, calculates waterflood recovery efficiency factor.
2, polymer flooding scheme:
1. the rock core after the water drive is carried out the polymer displacement of reservoir oil operation, the consumption of polymer solution is 0.6PV (rock pore volume);
2. follow-up water drive to rock core exports till the moisture 98v%, calculates to gather and drives recovery ratio;
3, foam and alkali/surfactant binary solution replaces injecting scheme:
The rock core model that will gather after driving alternately injects a certain amount of foam and alkali/surfactant binary solution; Last water drive to extraction liquid moisture content reaches till the 98v%; Calculate foam and alkali/surfactant binary solution and alternately inject the recovery ratio of the displacement of reservoir oil, specifically carry out according to following scheme.
Scheme is 1.: once inject foam 0.6PV and alkali/surfactant binary solution 0.3PV, the rock core coefficient of variation is respectively 0.6,0.72,0.8, three rock core and is designated as 0.6-1,0.72-1,0.8-1 respectively;
Scheme is 2.: inject foam 0.6PV and alkali/surfactant binary solution 0.3PV altogether; Equivalent is injected at twice; Alternately inject foam 0.3PV and alkali/surfactant system 0.15PV, the rock core coefficient of variation is that 0.6,0.72, two rock core is designated as 0.6-2,0.72-2 respectively at every turn;
Scheme is 3.: inject foam 0.6PV and alkali/surfactant binary solution 0.3PV altogether, divide three equivalent to inject.Alternately inject foam 0.2PV and alkali/surfactant binary solution 0.1PV, the rock core coefficient of variation is that 0.72,0.8, two rock core is designated as 0.72-3,0.8-2 respectively at every turn;
Scheme is 4.: inject foam 0.6PV and alkali/surfactant binary solution 0.3PV altogether; Divide four equivalent to inject; Alternately inject foam 0.15PV and alkali/surfactant binary solution 0.075PV, the rock core coefficient of variation is that 0.72,0.8, two rock core is designated as 0.72-4,0.8-4 respectively at every turn;
Scheme is 5.: inject foam 0.3PV and alkali/surfactant binary solution 0.12PV altogether, divide three equivalent to inject, alternately inject foam 0.1PV and alkali/surfactant binary solution 0.04PV at every turn, the rock core coefficient of variation is 0.8, and this rock core is designated as 0.8-3;
Annotate: in the above scheme, all do not have polymer in alkali/surfactant binary solution, it consists of alkali (NaOH): 1.2%, and surfactant (heavy alkylbenzene sulfonate): 0.3%;
Polymer concentration in the scheme foam liquid 1.-4. is 200mg/L, and the polymer concentration in the scheme foam liquid 5. is 1000mg/L.Gas in the foam liquid is natural gas, and gas-liquid volume ratio is 1: 1, and foaming agent concentration is 0.1wt%.When injecting, inject foam slug, the alkali that reinjects/surfactant binary solution slug earlier.
Three, experimental result
1, the rock core non-homogeneity is strong more, and ultimate recovery is low more
In table 1, for the different rock core of the coefficient of variation, under identical injection number of times; At alternate frequency is below 4 times the time; Its ultimate recovery reduces along with the increase of the coefficient of variation, and therefore, the non-homogeneity of rock core is conclusive to the influence of oil recovery factor; The enhancing of non-homogeneity reduces the ultimate recovery of crude oil.
2, the rock core non-homogeneity is to improving the influence of recovery ratio amplitude
In table 1, identical alternately injecting under the number of times, recovery ratio raising value reduced along with the increase of the rock core coefficient of variation before this, but when alternately injecting number of times and reach 4 times, opposite tendency occurred, and the coefficient of variation increases, and the amplitude that improves recovery ratio increases.
3, alternately inject the influence of number of times to oil displacement efficiency
Can find out also that from table 1 to the rock core of the same coefficient of variation, its ultimate recovery all increases with the increase of alternate frequency with the amplitude that improves recovery ratio.Because gas liquid ratio control difficulty is bigger, the foam slug is too small, and the error of gas liquid ratio is bigger, and the comparativity of experimental result can not guarantee that this experiment has been accomplished alternately to inject four times.
4, in the foam polymer concentration to the influence of oil displacement efficiency
Under the essentially identical situation of chemical agent cost; Rock core to the coefficient of variation identical (coefficient of variation is 0.8) has carried out contrast experiment's (scheme 5 and scheme 3); In table 1, can find out; The water drive oil of two blocks of rock cores and the recovery ratio of polymer displacement of reservoir oil are basic identical; But the ultimate recovery of high concentration polymer foam and alkali/surfactant binary solution (AS) will be lower than original prescription with the amplitude that improves recovery ratio, and promptly the effect of the big slug of low copolymer concentration is better than high polymer concentration pill.
Table 1 Physical simulation experiment
Four, chemical agent cost comparative analysis
According to 24000 yuan/ton of surfactant prices, 3000 yuan/ton of alkaline agent prices, 17000/ ton of calculating of polymer price:
1, foam and alkali/surfactant binary solution alternately injects the analysis of chemical agent use cost:
Expanding foam solution chemical agent cost per ton: 0.1% * 24000 yuan/ton+0.02% * 17000 yuan/ton=27.4 yuan
Alkali per ton/surfactant binary solution chemical agent cost: 0.3% * 24000 yuan/ton+1.2% * 3000 yuan/ton=108 yuan
Convert solution chemistry agent total cost per ton: 27.4+108=135.4 unit/ton
2, ternary composite driving chemical agent use cost is analyzed:
According to the ternary composite driving general procedure be: preposition polymer slug, polymer concentration 1500mg/L; The principal piece plug, alkali concn 1.2%, surfactant concentration 0.3%, polymer concentration 1500mg/L; Secondary slug, alkali concn 1.0%, surfactant concentration 0.2%, polymer concentration 1200mg/L; Rearmounted polymer slug, polymer concentration 1000mg/L;
Convert ASP flooding solution chemical agent total cost per ton: 0.15% * 17000 yuan/ton+0.3% * 24000 yuan/ton+1.2% * 3000 yuan/ton+0.15% * 17000 yuan/ton+0.2% * 24000 yuan/ton+1.0% * 3000 yuan/ton+0.12% * 17000 yuan/ton+0.10% * 17000 yuan/ton=274.4 yuan/ton
Can find out by above calculating; In the method provided by the present invention ton solution chemistry agent cost compare with ternary composite driving will be low many; And ternary composite driving drives the back and improves recovery ratio and be generally about 10% gathering; And this method is alternately being injected when reaching 4 times, and recovery ratio raising value is up to more than 20.9%, and very big advantage is arranged on economic benefit.
Claims (10)
1. method that improves the non-homogeneous pay recovery ratio; It is to replace with foam slug, alkali and surfactant binary solution slug to inject the method that improves the non-homogeneous pay recovery ratio; Said alternately the injection carried out 1-4 injection cycle; Wherein, inject the foam slug, and then inject alkali and surfactant binary solution slug is an injection cycle to oil reservoir;
The injection total amount of said foam slug is the 60%-100% of said oil reservoir total pore size volume; The injection total amount of said alkali and surfactant binary solution slug is the 30%-60% of said oil reservoir total pore size volume; And; The injection rate of said alkali and surfactant binary solution slug is 0.6mL/min, and the injection rate of said foam slug is 1.2mL/min.
2. method according to claim 1, wherein, said foam slug is made up of gas and expanding foam solution, and said expanding foam solution comprises first surface activating agent and polymer.
3. method according to claim 2, wherein, said expanding foam solution is the aqueous solution that contains first surface activating agent and polymer, and in this aqueous solution, the concentration of said first surface activating agent is 0.1wt%, the concentration of said polymer is 200mg/L.
4. according to claim 2 or 3 described methods, wherein, said first surface activating agent is an alpha-alkene sulfonate; Said polymer is a partially hydrolyzed polyacrylamide (PHPA); The relative molecular weight of this partially hydrolyzed polyacrylamide (PHPA) is 1,500 ten thousand, and degree of hydrolysis is 24%, and solid content is more than 90%.
5. according to claim 2 or 3 described methods, wherein, said gas is natural gas, and the volume ratio of said gas and said expanding foam solution is 1: 1.
6. method according to claim 1; Wherein, said alkali and surfactant binary solution slug are the aqueous solution of alkali and surfactant, in this aqueous solution; The concentration of said alkali is 0.8-1.2wt%, and said surfactant concentrations is 0.2-0.4wt%.
7. method according to claim 6, wherein, said alkali is NaOH.
8. according to claim 6 or 7 described methods, wherein, said surfactant is one or more in heavy alkylbenzene sulfonate, petroleum sulfonate and the betaine.
9. method according to claim 1, wherein, the oil reservoir that alternately is infused in of said foam slug, alkali and surfactant binary solution slug carries out carrying out after the polymer displacement of reservoir oil operation.
10. according to claim 1 or 9 described methods, wherein, this method may further comprise the steps:
Oil reservoir is carried out the water drive oil operation, reach more than 98% until extraction liquid moisture content;
Oil reservoir is carried out the polymer displacement of reservoir oil operation;
Once more oil reservoir is carried out the water drive oil operation, reach more than 98% until extraction liquid moisture content;
The foam slug, alkali and the surfactant binary solution slug that in oil reservoir, carry out 1-4 cycle alternately inject; The injection total amount of said foam slug is the 60%-100% of said oil reservoir total pore size volume; The injection total amount of said alkali and surfactant binary solution slug is the 30%-60% of said oil reservoir total pore size volume; The injection rate of said alkali and surfactant binary solution slug is 0.6mL/min, and the injection rate of said foam slug is 1.2mL/min.
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Cited By (6)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN104675370A (en) * | 2014-12-23 | 2015-06-03 | 东北石油大学 | Combinational flooding testing method capable of implementing gel injection and polymer solution injection alternately after water flooding |
| CN104929598A (en) * | 2015-06-24 | 2015-09-23 | 中国石油大学(北京) | Method for increasing foam swept volume |
| CN106468162A (en) * | 2015-08-21 | 2017-03-01 | 北京科技大学 | A kind of lab simulation core flooding test device and analogy method |
| CN107476788A (en) * | 2016-06-08 | 2017-12-15 | 中国石油天然气股份有限公司 | A kind of crude oil method for implanting |
| CN108425667A (en) * | 2018-05-11 | 2018-08-21 | 西南石油大学 | Visual polymer tune stream washing oil experimental provision |
| CN109796953A (en) * | 2019-03-26 | 2019-05-24 | 黑龙江信维源化工有限公司 | A kind of glycine betaine complex oil displacing composition |
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Cited By (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN104675370A (en) * | 2014-12-23 | 2015-06-03 | 东北石油大学 | Combinational flooding testing method capable of implementing gel injection and polymer solution injection alternately after water flooding |
| CN104675370B (en) * | 2014-12-23 | 2017-05-03 | 东北石油大学 | Combinational flooding testing method capable of implementing gel injection and polymer solution injection alternately after water flooding |
| CN104929598A (en) * | 2015-06-24 | 2015-09-23 | 中国石油大学(北京) | Method for increasing foam swept volume |
| CN106468162A (en) * | 2015-08-21 | 2017-03-01 | 北京科技大学 | A kind of lab simulation core flooding test device and analogy method |
| CN107476788A (en) * | 2016-06-08 | 2017-12-15 | 中国石油天然气股份有限公司 | A kind of crude oil method for implanting |
| CN108425667A (en) * | 2018-05-11 | 2018-08-21 | 西南石油大学 | Visual polymer tune stream washing oil experimental provision |
| CN109796953A (en) * | 2019-03-26 | 2019-05-24 | 黑龙江信维源化工有限公司 | A kind of glycine betaine complex oil displacing composition |
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Application publication date: 20120829 |