CN109386262A - Method and system for improving recovery ratio of water channeling layer - Google Patents
Method and system for improving recovery ratio of water channeling layer Download PDFInfo
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- CN109386262A CN109386262A CN201710682500.1A CN201710682500A CN109386262A CN 109386262 A CN109386262 A CN 109386262A CN 201710682500 A CN201710682500 A CN 201710682500A CN 109386262 A CN109386262 A CN 109386262A
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- 238000000034 method Methods 0.000 title claims abstract description 27
- 238000011084 recovery Methods 0.000 title claims abstract description 26
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title abstract description 33
- 230000005465 channeling Effects 0.000 title abstract description 7
- 239000004094 surface-active agent Substances 0.000 claims abstract description 21
- 241000772415 Neovison vison Species 0.000 claims description 51
- 238000002347 injection Methods 0.000 claims description 25
- 239000007924 injection Substances 0.000 claims description 25
- 239000006184 cosolvent Substances 0.000 claims description 9
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 8
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Natural products CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 5
- AMQJEAYHLZJPGS-UHFFFAOYSA-N N-Pentanol Chemical compound CCCCCO AMQJEAYHLZJPGS-UHFFFAOYSA-N 0.000 claims description 4
- 239000002202 Polyethylene glycol Substances 0.000 claims description 4
- LQZZUXJYWNFBMV-UHFFFAOYSA-N dodecan-1-ol Chemical compound CCCCCCCCCCCCO LQZZUXJYWNFBMV-UHFFFAOYSA-N 0.000 claims description 4
- 229920001223 polyethylene glycol Polymers 0.000 claims description 4
- 235000019441 ethanol Nutrition 0.000 claims description 3
- 230000008676 import Effects 0.000 claims description 3
- 239000008246 gaseous mixture Substances 0.000 claims description 2
- JMGZBMRVDHKMKB-UHFFFAOYSA-L disodium;2-sulfobutanedioate Chemical compound [Na+].[Na+].OS(=O)(=O)C(C([O-])=O)CC([O-])=O JMGZBMRVDHKMKB-UHFFFAOYSA-L 0.000 claims 1
- 125000005909 ethyl alcohol group Chemical group 0.000 claims 1
- 239000012530 fluid Substances 0.000 abstract description 11
- 238000004519 manufacturing process Methods 0.000 abstract description 5
- 239000000443 aerosol Substances 0.000 abstract 1
- 238000002791 soaking Methods 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 53
- 239000006210 lotion Substances 0.000 description 15
- 238000004088 simulation Methods 0.000 description 15
- 229920006395 saturated elastomer Polymers 0.000 description 10
- 239000010779 crude oil Substances 0.000 description 6
- 230000000694 effects Effects 0.000 description 6
- 230000015572 biosynthetic process Effects 0.000 description 5
- -1 polyoxyethylene groups Polymers 0.000 description 5
- 239000011435 rock Substances 0.000 description 5
- 239000000243 solution Substances 0.000 description 5
- 230000008569 process Effects 0.000 description 4
- 230000007423 decrease Effects 0.000 description 3
- 230000009467 reduction Effects 0.000 description 3
- 150000001336 alkenes Chemical class 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 230000002596 correlated effect Effects 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000001914 filtration Methods 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- OSOSMTZOKLTVFS-UHFFFAOYSA-N S(=O)(=O)(O)C(C(=O)O)CC(=O)O.C(C)C(C[Na])CCCC Chemical class S(=O)(=O)(O)C(C(=O)O)CC(=O)O.C(C)C(C[Na])CCCC OSOSMTZOKLTVFS-UHFFFAOYSA-N 0.000 description 1
- NIXOWILDQLNWCW-UHFFFAOYSA-N acrylic acid group Chemical group C(C=C)(=O)O NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000003213 activating effect Effects 0.000 description 1
- 229920002892 amber Polymers 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 230000000875 corresponding effect Effects 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000004090 dissolution Methods 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- 229940030188 solu-delta-cortef Drugs 0.000 description 1
- 235000020681 well water Nutrition 0.000 description 1
- 239000002349 well water Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
- E21B33/138—Plastering the borehole wall; Injecting into the formation
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P20/00—Technologies relating to chemical industry
- Y02P20/50—Improvements relating to the production of bulk chemicals
- Y02P20/54—Improvements relating to the production of bulk chemicals using solvents, e.g. supercritical solvents or ionic liquids
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Environmental & Geological Engineering (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
Abstract
The invention provides a method and a system for improving the recovery ratio of a water channeling layer. The method for improving the recovery ratio of the water channeling layer comprises the following steps of: 1) mixing an aerosol surfactant with supercritical CO2Mixing uniformly to obtain supercritical CO2Mixing the fluid; 2) subjecting the supercritical CO2Injecting the mixed fluid into the water channeling layer; 3) shutting down the well for soaking and then opening the well for production. The method can realize deep profile control and effective plugging of the water channeling layer, and greatly improves the recovery ratio of the water channeling layer.
Description
Technical field
The invention belongs to Oil-Gas Field Development Engineering technical fields, and in particular to it is a kind of improve mink layer recovery ratio method and
System.
Background technique
Hyposmosis oil in place is abundant in China's oil resource, covers the one third of national petroleum resources total amount, but
It is that the hyposmosis reserves employed only account for the half of gross reserves.Since low-permeability oilfield filtrational resistance is very big, oil well productivity very little is led to
Oil well output and individual well water injection capacity are improved frequently with hydraulic fracturing.However it is demonstrated experimentally that this development scheme water easy to form
Layer and fingering phenomenon are altered, to seriously constrain the development efficiency of low permeability oil and gas field.
With being on the rise for environmental problem, people increasingly pay close attention to CO2Influence to environment, while also to CO2Trap skill
Great expectations has been expressed in the development of art, wherein utilizing CO2Oil recovery factor is improved also increasingly to be approved both at home and abroad.However, practical
Using the result shows that: CO2Although viscous crude can be made to expand, its viscosity is reduced, so that oil output per well is improved to a certain extent,
However the effect for blocking transfer drive can not be played, and be easy to happen CO2Has channeling, effect are not obvious enough.In addition, routine CO2Lotion
Filtrational resistance in stratum is very big, is equally unfavorable for realizing effective closure of depth profile control and mink layer.
Summary of the invention
The present invention provides a kind of method and system for improving mink layer recovery ratio, can be realized depth profile control and to water breakthrough
Effective closure of layer, greatly improved the recovery ratio of mink layer.
The present invention provides a kind of method for improving mink layer recovery ratio, includes the steps that following sequence carries out:
1) by gas soluble surfactants and supercritical CO2It is uniformly mixed, obtains supercritical CO2Fluid-mixing；
2) by the supercritical CO2Fluid-mixing injects mink layer；
3) closing well carries out stewing well, then drives a well and is exploited.
In supercritical CO of the invention2In fluid-mixing, CO2It is in a supercritical state that (temperature and pressure is respectively at 31.1
DEG C and 7.38MPa or more), CO2Density close to fluid density, CO at this time2The mixed system of gas soluble surfactants is liquid-
Liquid dispersion is emulsion scope (referred to as CO2Lotion).
The method of raising mink layer recovery ratio of the invention is injected to mink layer and is faced dissolved with the super of gas soluble surfactants
Boundary CO2Fluid (i.e. supercritical CO2Fluid-mixing), mink layer, water layer or oil reservoir can be encountered in injection process；Face when super
Boundary CO2When fluid-mixing and oil reservoir meet, under the action of the factors such as temperature, pressure, supercritical CO2Fluid-mixing can be dissolved in ground
Layer crude oil, causes the density of in-place oil decline, dissolution viscosity reduction, volume expansion, to increase crude oil under formation conditions
Flowability reduces water-oil mobility ratio, and CO2Solubility in crude oil constantly increases with the increase of strata pressure
Greatly；And work as supercritical CO2When fluid-mixing and water layer or mink layer are met, due to supercritical CO2It is molten dissolved with gas in fluid-mixing
Property surfactant, CO can be formed in the earth formation under meeting after water the shearing of reservoir medium the effects of2Lotion, to realize
Closure to water layer and mink layer.After stewing well, during opening well and making production, water layer and mink layer are under stratum filtration effect
It is respectively formed CO2Lotion, flow resistance is big, is not easily accessible pit shaft, and oil reservoir is in supercritical CO2Pit shaft is flowed under fluid-mixing effect,
Improve the recovery ratio of mink layer.Especially since supercritical CO2The diffusivity and flowability of fluid-mixing are and gas phase
When flow resistance is small, will not form CO during injecting oil reservoir2Lotion is conducive to the production capacity for keeping oil reservoir, is furthermore conducive to
Water layer or mink layer are migrated to, to be conducive to realize depth profile control.
In the present invention, it is to be understood that gas soluble surfactants should be in supercritical CO2In have it is certain molten
Xie Du, to make supercritical CO2Fluid forms CO after meeting water2Lotion, the CO2After lotion vanishes in migration process, it is dissolved with gas
The supercritical CO of soluble surfactants2It can be emulsified again after being contacted with water flooding, to improve CO2Lotion it is shattered to pieces again
Natural disposition energy.
Preferably, the gas soluble surfactants (can be abbreviated as two (2- ethylhexyl) sodium sulfosuccinates
AOT) and/or lauryl alcohol polyethylene glycol oxide polyethenoxy ether (is abbreviated as C12E9P3；Wherein E represents polyoxyethylene groups, and P represents polyoxy
Acrylic), in supercritical CO2In have good solubility, mass concentration is up to 2.0% or more.
Further, in mixing, the gas soluble surfactants and supercritical CO be can control2Quality proportioning be
(0.2-3): 100；It can select suitable quality proportioning within the above range according to correlated conditions such as the moisture content of mink layer.
In particular, in gaseous mixture soluble surfactants and supercritical CO2When cosolvent is added, and can control described
Cosolvent and supercritical CO2Quality proportioning be (0.1-10): 100.Cosolvent is for increasing gas soluble surfactants super
Critical CO2In solubility, do not make considered critical to it, such as can be ethyl alcohol, amylalcohol etc..
Further, it is to be appreciated that CO should be made2It is mixed under conditions of in a supercritical state；Specifically, may be used
To carry out the mixing under conditions of temperature is 32 DEG C or more, absolute pressure is 7.4MPa or more.
Further, the supercritical CO2The injection rate of fluid-mixing can be 0.1-0.3PV；It can be according to mink layer
The correlated conditions such as moisture content select suitable injection rate within the above range.
In the present invention, temperature when can control stewing well is 50-150 DEG C, absolute pressure 20-120MPa.
The present invention also provides a kind of systems for improving mink layer recovery ratio, comprising:
For by gas soluble surfactants and supercritical CO2The mixing arrangement of mixing；
For injecting supercritical CO2The injection device of fluid-mixing is connected to the mixing arrangement；
For by supercritical CO2Fluid-mixing imports the injection well of mink layer, is connected to the injection device.
Further, the injection well includes wellhead assembly and the pit shaft that is connected to the wellhead assembly.
Implementation of the invention, at least has the advantage that
1, method of the invention injects supercritical CO to mink layer2Fluid-mixing can be dissolved in stratum when meeting with oil reservoir
Crude oil, so as to cause in-place oil density decline, dissolve viscosity reduction, volume expansion, increase crude oil under formation conditions can
Mobility reduces water-oil mobility ratio；CO can be formed in the earth formation when it meets with water layer or mink layer2Lotion, thus
Realize the closure to water layer and mink layer.
2, method of the invention is during opening well and making production, since water layer and mink layer are respectively formed under stratum filtration effect
CO2Lotion, flow resistance is big, is not easily accessible pit shaft, and oil reservoir is in supercritical CO2Pit shaft is flowed under fluid matasomatism, therefore is improved
The recovery ratio of mink layer；And supercritical CO2The diffusivity and flowability of fluid-mixing are worked as with gas phase, and flow resistance is small,
CO will not be formed during injecting oil reservoir2Lotion is conducive to keep the production capacity of oil reservoir and realizes depth profile control.
3, supercritical CO of the invention2Fluid forms CO after meeting water2Lotion, the CO2After lotion vanishes in migration process,
Supercritical CO dissolved with gas soluble surfactants2It can be emulsified again after being contacted with water flooding, to improve CO2Lotion
Shattered to pieces regenerability.
Detailed description of the invention
Fig. 1 is the injection process schematic diagram of the raising mink layer recovery ratio method of an embodiment of the present invention；
Fig. 2 is the recovery process schematic diagram of the raising mink layer recovery ratio method of an embodiment of the present invention.
Description of symbols:
1: mixing arrangement；2: injection device；3: wellhead assembly；4: pit shaft；5: oil reservoir；6: mink layer；7: reservoir.
Specific embodiment
To make the object, technical solutions and advantages of the present invention clearer, below in conjunction with the embodiment of the present invention and attached
Figure, technical scheme in the embodiment of the invention is clearly and completely described, it is clear that described embodiment is the present invention
A part of the embodiment, instead of all the embodiments.Based on the embodiments of the present invention, those of ordinary skill in the art are not having
Every other embodiment obtained under the premise of creative work is made, shall fall within the protection scope of the present invention.
Embodiment 1
The fine and close oil rock heart is placed in core holding unit, saturated water is first injected, is then injected into saturated oils, obtains simulation water breakthrough
Layer oil reservoir；Wherein, the temperature for simulating mink layer oil reservoir is 85 DEG C, experimental pressure 60MPa.
Under conditions of temperature is 60 DEG C, absolute pressure is 10MPa, by supercritical CO2, lauryl alcohol polyethylene glycol oxide polyoxy third
Alkene ether (C12E9P3) and cosolvent amylalcohol with mass ratio for 100:1:3 be uniformly mixed, be made supercritical CO2Fluid-mixing.
Above-mentioned supercritical CO is injected to above-mentioned simulation mink layer oil reservoir2Fluid-mixing, supercritical CO2The injection of fluid-mixing
Amount is 0.3PV, and closing well boils in a covered pot over a slow fire well for 24 hours under conditions of temperature is 85 DEG C, absolute pressure is 60MPa, then drives a well and exploited.
Through detecting, the recovery ratio of above-mentioned simulation mink layer oil reservoir is 29.1%.
Embodiment 2
The fine and close oil rock heart is placed in core holding unit, saturated water is first injected, is then injected into saturated oils, obtains simulation water breakthrough
Layer oil reservoir；Wherein, the temperature for simulating mink layer oil reservoir is 90 DEG C, experimental pressure 50MPa.
Under conditions of temperature is 60 DEG C, absolute pressure is 10MPa, by supercritical CO2, two (2- ethylhexyl) sulfo group ambers
Meticortene Solu-Delta-cortef and cosolvent ethyl alcohol are uniformly mixed with mass ratio for 100:1.5:4, and supercritical CO is made2Fluid-mixing.
Above-mentioned supercritical CO is injected to above-mentioned simulation mink layer oil reservoir2Fluid-mixing, supercritical CO2The injection of fluid-mixing
Amount is 0.25PV, and closing well boils in a covered pot over a slow fire well for 24 hours under conditions of temperature is 90 DEG C, absolute pressure is 50MPa, then drives a well and exploited.
Through detecting, the recovery ratio of above-mentioned simulation mink layer oil reservoir is 28.6%.
Embodiment 3
The fine and close oil rock heart is placed in core holding unit, saturated water is first injected, is then injected into saturated oils, obtains simulation water breakthrough
Layer oil reservoir；Wherein, the temperature for simulating mink layer oil reservoir is 80 DEG C, experimental pressure 60MPa.
Under conditions of temperature is 60 DEG C, absolute pressure is 10MPa, by supercritical CO2, lauryl alcohol polyethylene glycol oxide polyoxy third
Alkene ether (C12E9P3) and cosolvent amylalcohol with mass ratio for 100:0.8:2.5 be uniformly mixed, be made supercritical CO2Fluid-mixing.
Above-mentioned supercritical CO is injected to above-mentioned simulation mink layer oil reservoir2Fluid-mixing, supercritical CO2The injection of fluid-mixing
Amount is 0.2PV, and closing well boils in a covered pot over a slow fire well for 24 hours under conditions of temperature is 80 DEG C, absolute pressure is 60MPa, then drives a well and exploited.
Through detecting, the recovery ratio of above-mentioned simulation mink layer oil reservoir is 27.9%.
Embodiment 4
Referring to figs. 1 and 2, the system of raising mink layer recovery ratio of the invention, comprising: be used for gas dissolubility surface
Activating agent and supercritical CO2The mixing arrangement 1 of mixing；For injecting supercritical CO2The injection device 2 of fluid-mixing, and mixes
Device 1 is connected to；For by supercritical CO2Fluid-mixing imports the injection well of mink layer, is connected to injection device 2.
Specifically, injection well includes wellhead assembly 3 and the pit shaft being connected to wellhead assembly 34.
The system of raising mink layer recovery ratio of the invention can be used in the method for embodiment 1-3；Specifically, by gas dissolubility
Surfactant and supercritical CO2After mixing in mixing arrangement 1, supercritical CO is obtained2Fluid-mixing；The supercritical CO2Mixing
Fluid enters reservoir 7 through wellhead assembly 3 and pit shaft 4 by injection device 2, and in-place oil can be dissolved in when meeting with oil reservoir 5, from
And the density of in-place oil is caused to decline, and viscosity reduction is dissolved, volume expansion increases the flowability of crude oil under formation conditions,
Reduce water-oil mobility ratio；It can form CO when meeting with water layer or mink layer 6 in the earth formation2Lotion, to realize
Closure to water layer and mink layer 6.
Reference examples 1
The fine and close oil rock heart is placed in core holding unit, saturated water is first injected, is then injected into saturated oils, obtains simulation water breakthrough
Layer oil reservoir；Wherein, the temperature for simulating mink layer oil reservoir is 85 DEG C, experimental pressure 60MPa.
The pure CO of gas soluble surfactants is free of to the injection of above-mentioned simulation mink layer oil reservoir2Fluid, pure CO2The note of fluid
Entering amount is 0.3PV, and closing well boils in a covered pot over a slow fire well for 24 hours under conditions of temperature is 85 DEG C, absolute pressure is 60MPa, then drives a well out
It adopts.
Through detecting, the recovery ratio of above-mentioned simulation mink layer oil reservoir is 16.3%.
Reference examples 2
The fine and close oil rock heart is placed in core holding unit, saturated water is first injected, is then injected into saturated oils, obtains simulation water breakthrough
Layer oil reservoir；Wherein, the temperature for simulating mink layer oil reservoir is 85 DEG C, experimental pressure 60MPa.
By the CO of non-supercritical2It is mixed, is mixed for 100:1 with mass ratio with the surfactant solution of non-gas dissolubility
Fluid.
Above-mentioned fluid-mixing is injected to above-mentioned simulation mink layer oil reservoir, the injection rate of fluid-mixing is 0.3PV, closing well,
Well is boiled in a covered pot over a slow fire for 24 hours under conditions of temperature is 85 DEG C, absolute pressure is 60MPa, is then driven a well and is exploited.
Through detecting, the recovery ratio of above-mentioned simulation mink layer oil reservoir is 19.6%.
Finally, it should be noted that the above embodiments are only used to illustrate the technical solution of the present invention., rather than its limitations；To the greatest extent
Pipe present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that: its according to
So be possible to modify the technical solutions described in the foregoing embodiments, or to some or all of the technical features into
Row equivalent replacement；And these are modified or replaceed, various embodiments of the present invention technology that it does not separate the essence of the corresponding technical solution
The range of scheme.
Claims (10)
1. a kind of method for improving mink layer recovery ratio, which is characterized in that include the steps that following sequence carries out:
1) by gas soluble surfactants and supercritical CO2It is uniformly mixed, obtains supercritical CO2Fluid-mixing；
2) by the supercritical CO2Fluid-mixing injects mink layer；
3) closing well carries out stewing well, then drives a well and is exploited.
2. the method according to claim 1, wherein the gas soluble surfactants are two (2- ethylhexyls)
Sodium sulfosuccinate and/or lauryl alcohol polyethylene glycol oxide polyethenoxy ether.
3. the method according to claim 1, wherein mixing when, control the gas soluble surfactants with
Supercritical CO2Quality proportioning be (0.2-3): 100.
4. the method according to claim 1, wherein in gaseous mixture soluble surfactants and supercritical CO2Shi Jia
Enter cosolvent, and controls the cosolvent and supercritical CO2Quality proportioning be (0.1-10): 100.
5. according to the method described in claim 4, it is characterized in that, the cosolvent is ethyl alcohol or amylalcohol.
6. the method according to claim 1, wherein temperature be 32 DEG C or more, absolute pressure be 7.4MPa with
The mixing is carried out under conditions of upper.
7. the method according to claim 1, wherein the supercritical CO2The injection rate of fluid-mixing is 0.1-
0.3PV。
8. the method according to claim 1, wherein temperature when controlling stewing well is 50-150 DEG C, absolute pressure
For 20-120MPa.
9. a kind of system for improving mink layer recovery ratio characterized by comprising
For by gas soluble surfactants and supercritical CO2The mixing arrangement of mixing；
For injecting supercritical CO2The injection device of fluid-mixing is connected to the mixing arrangement；
For by supercritical CO2Fluid-mixing imports the injection well of mink layer, is connected to the injection device.
10. system according to claim 9, which is characterized in that the injection well include wellhead assembly and with the well head
The pit shaft of device connection.
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| CN201710682500.1A CN109386262A (en) | 2017-08-10 | 2017-08-10 | Method and system for improving recovery ratio of water channeling layer |
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| CN201710682500.1A CN109386262A (en) | 2017-08-10 | 2017-08-10 | Method and system for improving recovery ratio of water channeling layer |
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| CN106089166A (en) * | 2016-06-17 | 2016-11-09 | 中国石油大学(华东) | A kind of fine and close oil reservoir CO2foam handle up improve recovery ratio method |
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2017
- 2017-08-10 CN CN201710682500.1A patent/CN109386262A/en active Pending
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| CN102933680A (en) * | 2010-06-04 | 2013-02-13 | 陶氏环球技术有限责任公司 | Suspensions for enhanced oil recovery |
| CN102933681A (en) * | 2010-06-04 | 2013-02-13 | 陶氏环球技术有限责任公司 | Solubilizing surfactants into supercritical carbon dioxide for enhanced oil recovery |
| CN103867169A (en) * | 2014-04-02 | 2014-06-18 | 中国石油大学(华东) | Method for applying gas-soluble surfactant to fluidity control of carbon dioxide oil displacement |
| CN104194762A (en) * | 2014-08-04 | 2014-12-10 | 中国石油大学(北京) | Supercritical CO2 microemulsion and method for improving oil recovery factor |
| CN106089166A (en) * | 2016-06-17 | 2016-11-09 | 中国石油大学(华东) | A kind of fine and close oil reservoir CO2foam handle up improve recovery ratio method |
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