CN1632042A - Phase permeability modifying agent and method for improving recovery efficiency of crude oil by using same - Google Patents
Phase permeability modifying agent and method for improving recovery efficiency of crude oil by using same Download PDFInfo
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- CN1632042A CN1632042A CN 200410044098 CN200410044098A CN1632042A CN 1632042 A CN1632042 A CN 1632042A CN 200410044098 CN200410044098 CN 200410044098 CN 200410044098 A CN200410044098 A CN 200410044098A CN 1632042 A CN1632042 A CN 1632042A
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- relative permeability
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- 238000000034 method Methods 0.000 title claims abstract description 21
- 230000035699 permeability Effects 0.000 title claims description 73
- 238000011084 recovery Methods 0.000 title claims description 24
- 239000003795 chemical substances by application Substances 0.000 title claims description 12
- 239000010779 crude oil Substances 0.000 title abstract description 8
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 49
- 229920002401 polyacrylamide Polymers 0.000 claims abstract description 14
- 239000012530 fluid Substances 0.000 claims abstract description 8
- 239000003607 modifier Substances 0.000 claims description 64
- 239000000203 mixture Substances 0.000 claims description 9
- WSFSSNUMVMOOMR-UHFFFAOYSA-N Formaldehyde Chemical compound O=C WSFSSNUMVMOOMR-UHFFFAOYSA-N 0.000 claims description 6
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 6
- 230000007062 hydrolysis Effects 0.000 claims description 6
- 238000006460 hydrolysis reaction Methods 0.000 claims description 6
- 238000002347 injection Methods 0.000 claims description 6
- 239000007924 injection Substances 0.000 claims description 6
- 229920000642 polymer Polymers 0.000 claims description 6
- -1 alkylbenzene sulfonate Chemical class 0.000 claims description 5
- IKHGUXGNUITLKF-UHFFFAOYSA-N Acetaldehyde Chemical compound CC=O IKHGUXGNUITLKF-UHFFFAOYSA-N 0.000 claims description 4
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 claims description 4
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 4
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 4
- UIIMBOGNXHQVGW-UHFFFAOYSA-M Sodium bicarbonate Chemical compound [Na+].OC([O-])=O UIIMBOGNXHQVGW-UHFFFAOYSA-M 0.000 claims description 4
- 239000013543 active substance Substances 0.000 claims description 4
- 239000003513 alkali Substances 0.000 claims description 4
- 239000007864 aqueous solution Substances 0.000 claims description 4
- 229910052804 chromium Inorganic materials 0.000 claims description 4
- 239000011651 chromium Substances 0.000 claims description 4
- 239000003208 petroleum Substances 0.000 claims description 4
- BDERNNFJNOPAEC-UHFFFAOYSA-N propan-1-ol Chemical compound CCCO BDERNNFJNOPAEC-UHFFFAOYSA-N 0.000 claims description 4
- 150000003839 salts Chemical class 0.000 claims description 4
- UMGDCJDMYOKAJW-UHFFFAOYSA-N thiourea Chemical group NC(N)=S UMGDCJDMYOKAJW-UHFFFAOYSA-N 0.000 claims description 4
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 claims description 3
- 239000012266 salt solution Substances 0.000 claims description 3
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 claims description 2
- AMQJEAYHLZJPGS-UHFFFAOYSA-N N-Pentanol Chemical compound CCCCCO AMQJEAYHLZJPGS-UHFFFAOYSA-N 0.000 claims description 2
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims description 2
- DPDMMXDBJGCCQC-UHFFFAOYSA-N [Na].[Cl] Chemical compound [Na].[Cl] DPDMMXDBJGCCQC-UHFFFAOYSA-N 0.000 claims description 2
- 239000002671 adjuvant Substances 0.000 claims description 2
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 claims description 2
- 229910052782 aluminium Inorganic materials 0.000 claims description 2
- 239000004411 aluminium Substances 0.000 claims description 2
- 239000001110 calcium chloride Substances 0.000 claims description 2
- 229910001628 calcium chloride Inorganic materials 0.000 claims description 2
- 239000010865 sewage Substances 0.000 claims description 2
- 235000017557 sodium bicarbonate Nutrition 0.000 claims description 2
- 229910000030 sodium bicarbonate Inorganic materials 0.000 claims description 2
- 235000017550 sodium carbonate Nutrition 0.000 claims description 2
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 2
- 239000000243 solution Substances 0.000 claims description 2
- 239000002904 solvent Substances 0.000 claims description 2
- 239000004094 surface-active agent Substances 0.000 claims description 2
- 239000007788 liquid Substances 0.000 abstract description 5
- 230000000694 effects Effects 0.000 abstract description 3
- 239000000126 substance Substances 0.000 abstract description 2
- 238000005325 percolation Methods 0.000 abstract 6
- 239000003431 cross linking reagent Substances 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 57
- 239000011435 rock Substances 0.000 description 26
- 238000006073 displacement reaction Methods 0.000 description 16
- 238000002360 preparation method Methods 0.000 description 9
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 6
- 239000003153 chemical reaction reagent Substances 0.000 description 6
- 239000012190 activator Substances 0.000 description 5
- 238000011161 development Methods 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 5
- 230000008569 process Effects 0.000 description 5
- 230000009471 action Effects 0.000 description 4
- 230000008859 change Effects 0.000 description 4
- 230000009467 reduction Effects 0.000 description 4
- 239000004593 Epoxy Substances 0.000 description 3
- 238000005266 casting Methods 0.000 description 3
- WYYQVWLEPYFFLP-UHFFFAOYSA-K chromium(3+);triacetate Chemical compound [Cr+3].CC([O-])=O.CC([O-])=O.CC([O-])=O WYYQVWLEPYFFLP-UHFFFAOYSA-K 0.000 description 3
- 239000003350 kerosene Substances 0.000 description 3
- 229920005989 resin Polymers 0.000 description 3
- 239000011347 resin Substances 0.000 description 3
- 239000011780 sodium chloride Substances 0.000 description 3
- 229940077388 benzenesulfonate Drugs 0.000 description 2
- 150000002500 ions Chemical class 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 230000033764 rhythmic process Effects 0.000 description 2
- 238000004088 simulation Methods 0.000 description 2
- 239000011734 sodium Substances 0.000 description 2
- 229910052708 sodium Inorganic materials 0.000 description 2
- 125000000129 anionic group Chemical group 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 230000010534 mechanism of action Effects 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 235000010755 mineral Nutrition 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
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- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
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Abstract
Disclosed are phase percolation rate improver and the method of increasing crude oil producing by it, relating to a chemical agent-percolation rate improver for increasing crude oil producing in crude oil employment, and the method to increase crude oil producing by phase percolation rate improver. The phase percolation rate improver is comprised of 100-5000ppm polyacrylamide and 100-5000ppm cross linking agent, and the method to increase the productivity is as follows: inject percolation rate improver in large dosage into the water well, then use other displacing fluid to make waterdisplacing, polymerdisplacing or poly. The invention has realized increasing the productivity by several effect, it has the following characteristics: increasing the edge-water encroachment efficiency of wave and volume while injecting the phase percolation rate improver, after that increasing the edge-water encroachment efficiency in the course of injecting the waterdisplacing or displacing of other liquid.
Description
Technical field:
The present invention relates to a kind of chemical agent-relative permeability modifier that in oil reservoir development, improves oil recovery factor, and utilize relative permeability modifier to improve the method for oil recovery factor.
Background technology:
In the middle of a century of modern petroleum industry fast development, oil becomes the strong thruster that promotes the world economy high speed development.Current, most in the world oil fields enter the ripe productive life in succession, and oil is the digging mineral reserve of non-renewable (comparing with human evolution's history), how farthest to obtain more petroleum-based energy and has important decisive action for the Sustainable development of our times economy.Therefore, improve recovery efficiency technique and be subjected to worldwide extensive concern.In order further to excavate prospective oil, in recent years, the research and the test of a large amount of raising recovery efficiency techniques have all been actively developed both at home and abroad, mainly comprise technique of polymer flooding, polynaryly drive technology, mixed phase drives technology, depth profile control technology etc., obtained good mining site effect, but in order to obtain better effect, recovery ratio is further improved, lack the invention of new principle.
Summary of the invention:
The present invention is directed to the thick oil pay water drive and poly-drive exploitation back oil reservoir characteristics and a kind of relative permeability modifier is provided and utilizes its method that improves oil recovery factor, it has realized the purpose that reduces the measure cost, improve recovery ratio by multiple technologies mechanism.Relative permeability modifier of the present invention comprises polyacrylamide (PAM) and linking agent, and wherein the concentration of polyacrylamide is 100～5000ppm, and the concentration of linking agent is 100～5000ppm.Be achieved in that from well injection relative permeability modifier slug with its method that improves oil recovery factor, adopt other displacing fluids to carry out water drive, polymer flooding or polynary driving then.
Along with going deep into of oil-field development, in the water drive process, the water saturation of oil reservoir increases gradually, and the relative permeability of water improves, and the relative permeability of oil reduces.Relative permeability modifier has the performance that inequality proportion reduces the profit rate of permeation, can reduce water phase permeability significantly, and it is less relatively to the influence of permeability to oil, after adopting relative permeability modifier that the stratum is handled, the mobile water-oil ratio reduces, water saturation improves in its treatment zone, and residual oil saturation reduces.Before relative permeability modifier was handled, residual oil saturation was S
Or1, after relative permeability modifier was handled, residual oil saturation was S
Or2, the mobile water-oil ratio
If
Reduce N doubly, mobile water-oil ratio f
wJust reduce N doubly, therefore, oil phase relative current momentum increases in the relative permeability modifier treatment zone, and residual oil saturation reduces, and water saturation improves,
S
Or2＜S
Or1, therefore, relative permeability modifier improves the recovery ratio (see figure 1) by improving microscopic oil displacement efficiency.Simultaneously, relative permeability modifier has certain viscosity, in displacement relative permeability modifier process, improves oil displacement efficiency and swept volume by improving mobility ratio.On the thick-layer vertical profile, rate of permeation is gradual change, and for the stratum of positive rhythm, oil reservoir top rate of permeation is low, oil reservoir bottom rate of permeation height.What activator distributed on oil reservoir top lacks, it is many that activator distributes in the oil reservoir bottom, the distribution of relative permeability modifier on vertical profile is gradual change, swept volume also is gradual change, this just is equivalent to change the rhythm on stratum, make rate of permeation on the oil reservoir vertical profile, become even relatively, in the activator displacement process and in the follow-up water drive process, improved swept volume.The present invention is with to improve recovery efficiency technique different in the past, realizes improving the purpose of recovery ratio by multiple mechanism of action higher degree ground, and it has following characteristics:
1, increase swept volume and oil displacement efficiency during the injection relative permeability modifier:
1. relative permeability modifier utilizes its viscoelastic degree to improve oil displacement efficiency and swept volume as oil-displacing agent;
2. relative permeability modifier can reduce the rate of permeation of oil reservoir bottom significantly, makes rate of permeation become even relatively on the oil reservoir vertical profile, thereby improves swept volume;
2, follow-up water drive (or other liquid displacements) process after injecting relative permeability modifier improves oil displacement efficiency:
1. reduce the profit rate of permeation by inequality proportion, improve the water saturation in relative permeability modifier treatment zone and the range of influence thereof, reduce oil saturation, improve microscopic oil displacement efficiency and improve recovery ratio;
Reservoir permeability is become on vertical profile evenly, improve swept volume.
Description of drawings:
Fig. 1 reduces irreducible oil, improves the oil displacement efficiency principle schematic for relative permeability modifier.
Embodiment:
Embodiment one: the relative permeability modifier of present embodiment is made up of polyacrylamide (PAM) and linking agent, and wherein the concentration of polyacrylamide is 100～5000ppm, and the concentration of linking agent is 100～5000ppm.The molecular weight of described polyacrylamide is 100～4,000 ten thousand, and degree of hydrolysis is 0～40%; Described linking agent is one or more in organic chromium, inorganic chromium, organoaluminum and the inorganic aluminium.
Embodiment two: what present embodiment and embodiment one were different is, it also comprises the tensio-active agent that accounts for relative permeability modifier gross weight 0.001～0.2%, described tensio-active agent can be negatively charged ion, positively charged ion or nonionogenic tenside, as: sulfonated petro-leum or alkylbenzene sulfonate.Other compositions are identical with embodiment one with content.
Embodiment three: what present embodiment and embodiment one, two were different is, it also comprises the solubility promoter that accounts for relative permeability modifier gross weight 0.01～30.0%, and described solubility promoter is one or more in ethanol, propyl alcohol, Virahol, amylalcohol, formaldehyde and the acetaldehyde.Other compositions are identical with embodiment one, two with content.
Embodiment four: what present embodiment and embodiment one, two, three were different is, it also comprises the alkali that accounts for relative permeability modifier gross weight 0.1～5.0%, and described alkali is one or more in yellow soda ash, sodium bicarbonate and the sodium hydroxide.Other compositions are identical with embodiment one, two, three with content.
Embodiment five: what present embodiment and embodiment one, two, three, four were different is, it also comprises the salt that accounts for relative permeability modifier gross weight 0.01～5.0%, and described salt is one or more in sodium-chlor, Repone K and the calcium chloride.Other compositions are identical with embodiment one, two, three, four with content.
Embodiment six: what present embodiment and embodiment one, two, three, four, five were different is, it also comprises the stablizer that accounts for relative permeability modifier gross weight 0.01～5.0%, and described stablizer is a thiocarbamide.Other compositions are identical with embodiment one, two, three, four, five with content.
Embodiment seven: present embodiment is to utilize relative permeability modifier to improve oil recovery factor like this: heavy dose of relative permeability modifier slug that injects from the well, adopt displacing fluid to carry out water drive, polymer flooding or the polynary slug that drives then, described relative permeability modifier comprises polyacrylamide and linking agent, wherein the concentration of polyacrylamide is 100～5000ppm, and the concentration of linking agent is 100～5000ppm.The slug amount of described relative permeability modifier is 0.01～1.0% of an oil reservoir volume of voids (PV).Displacing fluid after the described relative permeability modifier slug is one or more the mixture in clear water, salt solution (salinity 100～100000), sewage, water phase surfactant mixture, aqueous solutions of polymers, solvent aqueous solution, the adjuvant water solution.Described relative permeability modifier slug and follow-up displacing fluid slug are periodically alternately to inject, and the injection cycle is arbitrary value of 1～100.
Embodiment eight: present embodiment is achieved in that
One, preparation relative permeability modifier D-RPM200 system:
(1) 200ppm partial hydrolysis anionic polyacrylamide (HPAM), Daqing oil field auxiliary reagent factory, degree of hydrolysis 25%;
(2) 20ppm chromium acetate, 1%NaCl, 0.1%NaCO
3, reagent;
(3) oil: the simulated oil of crude oil and kerosene preparation, 45 ℃ of following viscosity are 6.476mPas;
(4) water: form the Simulated Water of preparation, salinity 3700.0mg/L by injecting water;
(5) rock core: the Resins, epoxy artificial consolidated core of casting, air 1000 * 10
-3ц m
2
Two, injecting program:
(1) rock core is vacuumized, water filling is measured rock core size and volume of voids until saturated in the rock core;
(2) survey rock core water absolute permeability;
(3) in rock core, inject oil with the displacement pump with the constant flow, displacement simulation oil to rock core exports not to be had in the output liquid till the salt solution, simulation contains the reservoir condition of irreducible water, when the pressure reduction at rock core two ends is constant, the pressure reduction and the aquifer yield at record rock core two ends calculate oil phase end points rate of permeation and irreducible water saturation;
(4) inject water with the displacement pump with the constant flow in rock core, when moisture when reaching 98% in the rock core outlet output liquid, the pressure reduction and the oil pump capacity at record rock core two ends are calculated the recovery ratio of oil saturation after the water drive, water phase permeability and raising;
(5) the relative permeability modifier D-RPM200 of forward displacement 0.25PV rock pore volume;
(6) will drive rock core constant temperature 10d under 45 ℃ of conditions of activator;
(7) in rock core, inject water with the displacement pump with the constant flow, when moisture when reaching 98% in the rock core outlet output liquid, the pressure reduction and the oil pump capacity at record rock core two ends, the recovery ratio of oil saturation, water phase permeability and raising behind the calculating injection relative permeability modifier.
After injecting relative permeability modifier D-RPM200, water drive reaches at 98% o'clock to exporting water ratio, relative permeability modifier treatment zone rock core water saturation is increased to 80% by 55%, and the relative permeability modifier zone of action is 40% of a rock core length, improves 4.47% than waterflood recovery efficiency factor.
Embodiment nine: present embodiment is achieved in that
One, preparation relative permeability modifier D-RPM300 system:
(1) 300ppmHPAM, Daqing oil field auxiliary reagent factory, degree of hydrolysis 25%;
(2) 30ppm chromium acetate, 1%NaCl, 0.1% Virahol, 0.1% sodium alkyl benzene sulfonate, reagent:
(3) oil: the simulated oil of crude oil and kerosene preparation, 45 ℃ of following viscosity are 6.476mPas;
(4) water: form the Simulated Water of preparation, salinity 3700.0mg/L by injecting water;
(5) rock core: the Resins, epoxy artificial consolidated core of casting, air 1000 * 10
-3ц m
2
Two, injecting program is with embodiment eight;
After injecting relative permeability modifier D-RPM300, water drive reaches at 98% o'clock to exporting water ratio, relative permeability modifier treatment zone rock core water saturation is increased to 74% by 55%, and the relative permeability modifier zone of action is 43% of a rock core length, improves 7.3% than waterflood recovery efficiency factor.
Embodiment ten: present embodiment is achieved in that
One, preparation relative permeability modifier D-RPM500 system:
(1) 500ppmHPAM, Daqing oil field auxiliary reagent factory, degree of hydrolysis 25%;
(2) 60ppm chromium acetate, 1%NaCl, 0.2% sodium alkyl benzene sulfonate, reagent;
(3) oil: the simulated oil of crude oil and kerosene preparation, 45 ℃ of following viscosity are 6.476mPas;
(4) water: form the Simulated Water of preparation, salinity 3700.0mg/L by injecting water;
(5) rock core: the Resins, epoxy artificial consolidated core of casting, air 1000 * 10
-3ц m
2
Two, injecting program:
Remove the relative permeability modifier D-RPM500 of (5) forward displacement 0.33PV rock pore volume; Other processing steps and parameter are with embodiment eight;
After injecting relative permeability modifier D-RPM500, water drive reaches at 98% o'clock to exporting water ratio, relative permeability modifier treatment zone rock core water saturation is increased to 84% by 55%, and the activator zone of action is 50% of a rock core length, improves 12.95% than waterflood recovery efficiency factor.
Claims (10)
1, relative permeability modifier is characterized in that it comprises polyacrylamide and linking agent, and wherein the concentration of polyacrylamide is 100～5000ppm, and the concentration of linking agent is 100～5000ppm.
2, described relative permeability modifier according to claim 1, the molecular weight that it is characterized in that described polyacrylamide is 100～4,000 ten thousand, degree of hydrolysis is 0～40%, and described linking agent is one or more in organic chromium, inorganic chromium, organoaluminum and the inorganic aluminium.
3, described relative permeability modifier according to claim 1 is characterized in that it also comprises the tensio-active agent that accounts for relative permeability modifier gross weight 0.001～0.2%, and described tensio-active agent is sulfonated petro-leum or alkylbenzene sulfonate.
4, described relative permeability modifier according to claim 1 and 2, it is characterized in that it also comprises the solubility promoter that accounts for relative permeability modifier gross weight 0.01～30.0%, described solubility promoter is one or more in ethanol, propyl alcohol, Virahol, amylalcohol, formaldehyde and the acetaldehyde.
5, described relative permeability modifier according to claim 4 is characterized in that it also comprises the alkali that accounts for relative permeability modifier gross weight 0.1～5.0%, and described alkali is one or more in yellow soda ash, sodium bicarbonate and the sodium hydroxide.
6, described according to claim 1 or 5 relative permeability modifier, it is characterized in that it also comprises the salt that accounts for relative permeability modifier gross weight 0.01～5.0% and 0.01～5.0% stablizer, described stablizer is a thiocarbamide, and described salt is one or more in sodium-chlor, Repone K and the calcium chloride.
7, utilize relative permeability modifier to improve the method for oil recovery factor, it is characterized in that it is achieved in that from well injection relative permeability modifier slug, adds displacing fluid then and carries out water drive, polymer flooding or the polynary slug that drives.
8, the method for utilizing relative permeability modifier to improve recovery ratio according to claim 7, the slug amount that it is characterized in that described relative permeability modifier is 0.01～1.0% of an oil reservoir volume of voids.
9, the method for utilizing relative permeability modifier to improve recovery ratio according to claim 7 is characterized in that described displacing fluid is one or more the mixture in clear water, salt solution, sewage, water phase surfactant mixture, aqueous solutions of polymers, solvent aqueous solution, the adjuvant water solution.
10, the method for utilizing relative permeability modifier to improve recovery ratio according to claim 7 is characterized in that relative permeability modifier slug and follow-up displacing fluid slug for periodically alternately injecting, and the injection cycle is arbitrary value of 1～100.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CNB2004100440987A CN100526415C (en) | 2004-12-01 | 2004-12-01 | Phase permeability modifying agent and method for improving recovery efficiency of crude oil by using same |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CNB2004100440987A CN100526415C (en) | 2004-12-01 | 2004-12-01 | Phase permeability modifying agent and method for improving recovery efficiency of crude oil by using same |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN1632042A true CN1632042A (en) | 2005-06-29 |
| CN100526415C CN100526415C (en) | 2009-08-12 |
Family
ID=34845973
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|---|---|---|---|
| CNB2004100440987A Expired - Fee Related CN100526415C (en) | 2004-12-01 | 2004-12-01 | Phase permeability modifying agent and method for improving recovery efficiency of crude oil by using same |
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| CN (1) | CN100526415C (en) |
Cited By (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101975051A (en) * | 2010-10-19 | 2011-02-16 | 大庆油田有限责任公司 | Chemical flooding alternate injection method |
| CN101362940B (en) * | 2008-09-05 | 2011-09-28 | 大庆油田有限责任公司 | Profile control agent of injection well |
| CN101418680B (en) * | 2007-10-23 | 2011-12-14 | 王长俊 | Gas lift unblocking technology by chemical method |
| CN103476899A (en) * | 2010-12-27 | 2013-12-25 | 艾尼股份公司 | Method for recovering oil from a reservoir by means of micro (nano)-structured fluids with controlled release of barrier substances |
| CN103666422A (en) * | 2013-12-04 | 2014-03-26 | 天津大港油田滨港集团博弘石油化工有限公司 | High-strength dilatation-retarding particle deep fluid diverting agent |
| CN105199703A (en) * | 2015-08-24 | 2015-12-30 | 中国石油化工股份有限公司 | High-temperature-resistant low-crosslinking ternary controlling and displacing agent and preparation method thereof |
| CN106285589A (en) * | 2016-08-16 | 2017-01-04 | 中国石油化工股份有限公司 | A kind of method improving ternary composite driving recovery ratio |
| CN115873569A (en) * | 2022-09-21 | 2023-03-31 | 中国石油化工股份有限公司 | Gel formation accelerant for profile control agent and application of gel formation accelerant in gel profile control agent |
-
2004
- 2004-12-01 CN CNB2004100440987A patent/CN100526415C/en not_active Expired - Fee Related
Cited By (10)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101418680B (en) * | 2007-10-23 | 2011-12-14 | 王长俊 | Gas lift unblocking technology by chemical method |
| CN101362940B (en) * | 2008-09-05 | 2011-09-28 | 大庆油田有限责任公司 | Profile control agent of injection well |
| CN101975051A (en) * | 2010-10-19 | 2011-02-16 | 大庆油田有限责任公司 | Chemical flooding alternate injection method |
| CN103476899A (en) * | 2010-12-27 | 2013-12-25 | 艾尼股份公司 | Method for recovering oil from a reservoir by means of micro (nano)-structured fluids with controlled release of barrier substances |
| CN103666422A (en) * | 2013-12-04 | 2014-03-26 | 天津大港油田滨港集团博弘石油化工有限公司 | High-strength dilatation-retarding particle deep fluid diverting agent |
| CN105199703A (en) * | 2015-08-24 | 2015-12-30 | 中国石油化工股份有限公司 | High-temperature-resistant low-crosslinking ternary controlling and displacing agent and preparation method thereof |
| CN105199703B (en) * | 2015-08-24 | 2018-05-22 | 中国石油化工股份有限公司 | A kind of high temperature resistant low cross-linking ternary profile control agent and preparation method thereof |
| CN106285589A (en) * | 2016-08-16 | 2017-01-04 | 中国石油化工股份有限公司 | A kind of method improving ternary composite driving recovery ratio |
| CN106285589B (en) * | 2016-08-16 | 2019-06-25 | 中国石油化工股份有限公司 | A method of improving ternary composite driving recovery ratio |
| CN115873569A (en) * | 2022-09-21 | 2023-03-31 | 中国石油化工股份有限公司 | Gel formation accelerant for profile control agent and application of gel formation accelerant in gel profile control agent |
Also Published As
| Publication number | Publication date |
|---|---|
| CN100526415C (en) | 2009-08-12 |
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