CN106479470A - Improve low-tension foaming agent and the flooding method of heterogeneous reservoir oil recovery factor - Google Patents
Improve low-tension foaming agent and the flooding method of heterogeneous reservoir oil recovery factor Download PDFInfo
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- CN106479470A CN106479470A CN201510547631.XA CN201510547631A CN106479470A CN 106479470 A CN106479470 A CN 106479470A CN 201510547631 A CN201510547631 A CN 201510547631A CN 106479470 A CN106479470 A CN 106479470A
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- 239000004088 foaming agent Substances 0.000 title claims abstract description 34
- 238000011084 recovery Methods 0.000 title claims abstract description 34
- 238000000034 method Methods 0.000 title claims abstract description 22
- 239000006260 foam Substances 0.000 claims abstract description 51
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 44
- 238000002347 injection Methods 0.000 claims abstract description 31
- 239000007924 injection Substances 0.000 claims abstract description 31
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 27
- 239000007864 aqueous solution Substances 0.000 claims abstract description 23
- -1 alkyl betaine Chemical compound 0.000 claims abstract description 18
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 18
- 239000003570 air Substances 0.000 claims abstract description 17
- 229910052757 nitrogen Inorganic materials 0.000 claims abstract description 14
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 13
- 239000011148 porous material Substances 0.000 claims abstract description 13
- 239000012530 fluid Substances 0.000 claims abstract description 10
- 239000003345 natural gas Substances 0.000 claims abstract description 9
- KWIUHFFTVRNATP-UHFFFAOYSA-N Betaine Natural products C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 claims abstract description 7
- 229960003237 betaine Drugs 0.000 claims abstract description 7
- 239000003381 stabilizer Substances 0.000 claims abstract description 4
- 239000007788 liquid Substances 0.000 claims description 11
- RTZKZFJDLAIYFH-UHFFFAOYSA-N ether Substances CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 7
- GLDOVTGHNKAZLK-UHFFFAOYSA-N octadecan-1-ol Chemical compound CCCCCCCCCCCCCCCCCCO GLDOVTGHNKAZLK-UHFFFAOYSA-N 0.000 claims description 6
- HLZKNKRTKFSKGZ-UHFFFAOYSA-N tetradecan-1-ol Chemical compound CCCCCCCCCCCCCCO HLZKNKRTKFSKGZ-UHFFFAOYSA-N 0.000 claims description 6
- 239000002253 acid Substances 0.000 claims description 5
- 239000007789 gas Substances 0.000 claims description 5
- KKMIHKCGXQMFEU-UHFFFAOYSA-N 2-[dimethyl(tetradecyl)azaniumyl]acetate Chemical compound CCCCCCCCCCCCCC[N+](C)(C)CC([O-])=O KKMIHKCGXQMFEU-UHFFFAOYSA-N 0.000 claims description 3
- TYIOVYZMKITKRO-UHFFFAOYSA-N 2-[hexadecyl(dimethyl)azaniumyl]acetate Chemical compound CCCCCCCCCCCCCCCC[N+](C)(C)CC([O-])=O TYIOVYZMKITKRO-UHFFFAOYSA-N 0.000 claims description 3
- 229940043348 myristyl alcohol Drugs 0.000 claims description 3
- GOQYKNQRPGWPLP-UHFFFAOYSA-N n-heptadecyl alcohol Natural products CCCCCCCCCCCCCCCCCO GOQYKNQRPGWPLP-UHFFFAOYSA-N 0.000 claims description 3
- BXWNKGSJHAJOGX-UHFFFAOYSA-N hexadecan-1-ol Chemical compound CCCCCCCCCCCCCCCCO BXWNKGSJHAJOGX-UHFFFAOYSA-N 0.000 claims 2
- 229960000541 cetyl alcohol Drugs 0.000 claims 1
- 239000000463 material Substances 0.000 claims 1
- 239000000203 mixture Substances 0.000 claims 1
- 229920000609 methyl cellulose Polymers 0.000 abstract description 5
- 239000001923 methylcellulose Substances 0.000 abstract description 5
- 239000002994 raw material Substances 0.000 abstract description 5
- 239000008399 tap water Substances 0.000 abstract description 5
- 235000020679 tap water Nutrition 0.000 abstract description 5
- 238000006073 displacement reaction Methods 0.000 description 13
- 229920000642 polymer Polymers 0.000 description 5
- 238000011161 development Methods 0.000 description 4
- 238000002474 experimental method Methods 0.000 description 4
- 238000005187 foaming Methods 0.000 description 4
- 235000016068 Berberis vulgaris Nutrition 0.000 description 3
- 241000335053 Beta vulgaris Species 0.000 description 3
- SNRUBQQJIBEYMU-UHFFFAOYSA-N Dodecane Natural products CCCCCCCCCCCC SNRUBQQJIBEYMU-UHFFFAOYSA-N 0.000 description 3
- 239000003513 alkali Substances 0.000 description 3
- 125000003438 dodecyl group Chemical group [H]C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])* 0.000 description 3
- 150000003839 salts Chemical class 0.000 description 3
- 230000000903 blocking effect Effects 0.000 description 2
- 150000007942 carboxylates Chemical class 0.000 description 2
- 238000004891 communication Methods 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- RZJRJXONCZWCBN-UHFFFAOYSA-N octadecane Chemical compound CCCCCCCCCCCCCCCCCC RZJRJXONCZWCBN-UHFFFAOYSA-N 0.000 description 2
- 230000035699 permeability Effects 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 125000005233 alkylalcohol group Chemical group 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 239000002585 base Substances 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000009533 lab test Methods 0.000 description 1
- QJGQUHMNIGDVPM-UHFFFAOYSA-N nitrogen group Chemical group [N] QJGQUHMNIGDVPM-UHFFFAOYSA-N 0.000 description 1
- 229940038384 octadecane Drugs 0.000 description 1
- 239000002332 oil field water Substances 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
Classifications
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- 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
-
- 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
- C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
-
- 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
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- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Lubricants (AREA)
Abstract
The present invention provides a kind of low-tension foaming agent for improving heterogeneous reservoir oil recovery factor and flooding method, and the low-tension foam of the raising heterogeneous reservoir oil recovery factor is made up of the raw material of following weight percent proportioning：Host 40～60, foam stabiliser 3～15, alkyl betaine 8～15, contracting methylcellulose 0.1～3, remaining for city tap-water.The flooding method is carried out as follows：A. first take low-tension foaming agent and add water and the aqueous solution is configured to, be then injected into implementing the water injection well of low-tension foam flooding, as preposed attributives；B. take low-tension foaming agent and add water and be configured to the aqueous solution, the aqueous solution is mixed the water injection well of the low-tension foam flooding described in injection a step with nitrogen, air or natural gas, injection rate is 0.2～0.4 times amount of formation pore body, forms foam flooding fluid, carries out low-tension foam flooding.
Description
Technical field
The present invention relates to ultra-high water cut stage heterogeneous reservoir improves recovery ratio method, more particularly to a kind of raising heterogeneous reservoir is former
The low-tension foaming agent of oil recovery and flooding method.
Background technology
, used as energy basis, the strategic importance in national development is most important for oil.East oilfields through exploitation for many years,
Most of oil field has been enter into ultra-high water cut stage, particularly main force oil field and faces aqueous high, recovery percent of reserves height, rate of oil production height
Development situation, exploitation stable yields difficulty increases, and conventional waterflooding development technique is difficult to slow down oil production successively decreases, stable yields situation ratio
Severeer.But part oilfield water flooding demarcation recovery ratio is relatively low, less than 30%, i.e., after water drive, in oil reservoir, still there is abundant remaining
Excess oil and larger potentiality to be exploited.Under these circumstances, recoverable reserves to be increased and raising crude output, it is necessary to seek new
Development technique.
It is more ripe tertiary oil recovery technology that polymer flooding and binary are driven at present, and industrial application is relatively more, but
The problem that high-quality three adopts scarcity of resources is faced with, therefore urgently researches and develops new flooding method.
Foam flooding is due to its good sealing characteristics and to oil-water selectivity and wide in variety, the strong spy of heat-resistant salt-resistant ability
Point, it is considered to be a rising tertiary oil recovery mode.But foam belongs to a kind of unstable state in itself,
Especially in the presence of residual oil, less stable, good shut-off capacity is hardly formed, foam flooding effect is affected.
Although adding polymer in foam system can increase the stability of foam, adding polymer will not only increase chemistry
The cost of agent, ground put into greatly, and polymer is very sensitive for water quality, temperature, salinity, shearing etc., viscosity
Fall is big, in oxygen, also can cause fatal impact to polymer viscosity.Therefore, low-tension foam flooding is sought
New method, develops and has high foaming properties while low-tension foam system with good oil-water interfaces performance, for subtracting
Few cost, the high temperature and high salt oil deposit oil recovery factor for improving ultra-high water cut stage further are significant.
Content of the invention
The purpose of the present invention is intended to overcome the deficiencies in the prior art, one of purpose be provide a kind of have high foaming properties, with
When have good oil-water interfaces performance raising heterogeneous reservoir oil recovery factor low-tension foaming agent；The two of purpose are to carry
For the method that a kind of low-tension foaming agent of the raising heterogeneous reservoir oil recovery factor of one of application target continues the displacement of reservoir oil.
An object of the present invention can be achieved by the following technical measures：
Improve the low-tension foaming agent of heterogeneous reservoir oil recovery factor, it is characterised in that it is by following weight percent proportioning
Raw material constitutes：
40～60 foam stabiliser 3～15 of host
8～15 contracting methylcellulose 0.1～3 of alkyl betaine
Water surplus.
An object of the present invention can also be achieved by the following technical measures：
Water of the present invention adopts city tap-water.
Described host be Brij 35 carboxylate, myristyl alcohol polyethenoxy ether carboxylate, 16
Alkyl alcohol ethoxylates carboxylate, stearyl alcohol polyethenoxy ether carboxylate.
Described foam stabiliser is cocinic acid MEA.
Described alkyl betaine is empgen BB, myristyl betaine, cetyl betaine, octadecane
Base glycine betaine.
The second object of the present invention can be achieved by the following technical measures：
The method for the displacement of reservoir oil being carried out using the low-tension foaming agent of the raising heterogeneous reservoir oil recovery factor of one of above-mentioned purpose,
The flooding method is carried out as follows：
A. first take low-tension foaming agent to add water the aqueous solution for being configured to that weight concentration is 0.8～1.2%, quantity is formation pore
0.01～0.05 times amount of volume, is then injected into implementing the water injection well of low-tension foam flooding, as preposed attributives；
B. take low-tension foaming agent to add water the aqueous solution for being configured to that weight concentration is 0.3～0.7%, by the aqueous solution and nitrogen,
The water injection well of the low-tension foam flooding described in air or natural gas mixing injection a step, injection rate be formation pore body 0.2～
0.4 times amount, it is to calculate and control liquid, gas according to subsurface volume ratio that the aqueous solution is mixed with nitrogen, air or natural gas
Product is than being 1：0.01～2, foam flooding fluid is formed, carries out low-tension foam flooding.
Low-tension foam flooding method in the present invention, is steeped by injection low-tension in ultra-high water cut stage heterogeneous reservoir
Foam fluid, on the one hand, (i.e. through a large amount of waterflood flushes, form fixing water in the low region of hypertonic, residual oil saturation
The region of circulation road), effective foam blocking is formed, displacement of reservoir oil fluid communication passage is blocked, expand displacement of reservoir oil fluid swept volume,
Which is forced to flow to the high region of hypotonic, residual oil saturation；On the other hand, foam flooding fluid is satisfied in hypotonic, residual oil
The region high with degree, plays the strong feature of its " low-tension " washing oil ability, improves displacement efficiency.Cooperate with terms of the two
The displacement of reservoir oil, displacement efficiency is improved, so as to reach the purpose for improving ultra-high water cut stage heterogeneous reservoir oil recovery factor.
Low-tension foam flooding method in the present invention, it is adaptable to high temperature and high salt, heterogeneous body, ultra-high water cut stage oil reservoir, gathers
Compound drives and binary drives the block that cannot be applied.The main performance index of low-tension foaming agent includes ultralow under reservoir condition
(requirement reaches 10 to oil water interfacial tension-3MN/m) and stronger foaming properties (foaming volume be more than 150mL, half foam life period
Require more than 60min), it is more than after 98% heterogeneous reservoir Produced Liquid is aqueous, laboratory test improves oil recovery factor 20%
More than, filed application improves oil recovery factor more than 10%.
Description of the drawings
Fig. 1 is the drive physical analogue experiment recovery ratio, aqueous of low-tension nitrogen foam flooding method in embodiments of the invention
Change curve；
Fig. 2 is the drive physical analogue experiment height osmole of low-tension nitrogen foam flooding method in the case study on implementation of the present invention
Type produces liquid fraction change curve.
For target block reservoir condition, the oil water interfacial tension that can reduce of the present invention is selected to have good foam performance again
Low-tension foaming agent be configured to 0.8～1.2% (w/t) solution, used as preposed attributives, low-tension foam flooding is implemented in injection
Water injection well, quantity are 0.01～0.05 times of formation pore volume；Then low-tension foaming agent is configured to 0.3～0.7% (w/t)
Solution, is mixed with nitrogen, air or natural gas, injects water injection well, is formed foam flooding fluid, is carried out low-tension foam
The displacement of reservoir oil, gas liquid ratio (subsurface volume ratio) are (0.01～2)：1, quantity is about 0.2～0.4 times of formation pore volume.
As shown in figure 1, in the drive physical analogue experiment of simulated target oil reservoir, non-homogeneous model comprehensive recovery and aqueous
Change curve.Can be seen that in non-homogeneous model from figure data, water drive reaches aqueous after being more than 98%, carries out low
Power nitrogen foam drives, and recovery ratio rises to 89% from 40%, and recovery ratio improves 49%；Aqueous decline 50%.
As shown in Fig. 2 in the drive physical analogue experiment of simulated target oil reservoir, height osmole type produces liquid fraction and injection rate
Relation curve, after injection low-tension nitrogen foam, height osmole type produces liquid to be occurred substantially to invert, it was confirmed that on simulation ground
The low region of residual oil saturation in layer, forms effective foam blocking, blocks displacement of reservoir oil fluid communication passage, expand drive
Flow of oil swept volume, improves heterogeneous reservoir ultra-high water cut stage oil recovery factor.
(non-homogeneous model：Height osmole type permeability is respectively 1.02,2.95 μm 2, and permeability grade is close to 3：1；Examination
Test temperature：80℃；Injection rate：1mL/min；Gas liquid ratio：1：1.)
Specific embodiment：
Embodiment 1：
The low-tension foaming agent of the raising heterogeneous reservoir oil recovery factor is made up of the raw material of following weight percent proportioning：
40% Brij 35 carboxylate, 15% cocinic acid MEA, 8% dodecyl beet
Alkali, 3% contracting methylcellulose and 34% city tap-water.
The method of the displacement of reservoir oil is carried out by following step using the low-tension foaming agent of the raising heterogeneous reservoir oil recovery factor of the present invention
Suddenly carry out：
A. first take low-tension foaming agent to add water the aqueous solution for being configured to that weight concentration is 0.8%, quantity is formation pore volume
0.05 times amount, is then injected into implementing the water injection well of low-tension foam flooding, as preposed attributives；
B. take low-tension foaming agent to add water the aqueous solution for being configured to that weight concentration is 0.7%, by the aqueous solution and nitrogen, air
Or the water injection well of the low-tension foam flooding described in natural gas mixing injection a step, injection rate is 0.2 times amount of formation pore body,
It is to calculate and control liquid, air volume ratio for 1 according to subsurface volume ratio that the aqueous solution is mixed with air：2, form foam flooding
Flow of oil, carries out low-tension foam flooding.
Embodiment 2：
The low-tension foaming agent of the raising heterogeneous reservoir oil recovery factor is made up of the raw material of following weight percent proportioning：
60% Brij 35 carboxylate, 3% cocinic acid MEA, 15% dodecyl beet
Alkali, 0.1% contracting methylcellulose and 21.9% city tap-water.
The method of the displacement of reservoir oil is carried out by following step using the low-tension foaming agent of the raising heterogeneous reservoir oil recovery factor of the present invention
Suddenly carry out：
A. first take low-tension foaming agent to add water the aqueous solution for being configured to that weight concentration is 1.2%, quantity is formation pore volume
0.01 times amount, is then injected into implementing the water injection well of low-tension foam flooding, as preposed attributives；
B. take low-tension foaming agent to add water the aqueous solution for being configured to that weight concentration is 0.3%, by the aqueous solution and nitrogen, air
Or the water injection well of the low-tension foam flooding described in natural gas mixing injection a step, injection rate is 0.4 times amount of formation pore body,
It is to calculate and control liquid, air volume ratio for 1 according to subsurface volume ratio that the aqueous solution is mixed with air：0.01, form foam
Displacement of reservoir oil fluid, carries out low-tension foam flooding.
Embodiment 3：
The low-tension foaming agent of the raising heterogeneous reservoir oil recovery factor is made up of the raw material of following weight percent proportioning：
50% Brij 35 carboxylate, 10% cocinic acid MEA, 12% dodecyl beet
Alkali, 3% contracting methylcellulose and 25% city tap-water.
The method of the displacement of reservoir oil is carried out by following step using the low-tension foaming agent of the raising heterogeneous reservoir oil recovery factor of the present invention
Suddenly carry out：
A. first take low-tension foaming agent to add water the aqueous solution for being configured to that weight concentration is 1.0%, quantity is formation pore volume
0.03 times amount, is then injected into implementing the water injection well of low-tension foam flooding, as preposed attributives；
B. take low-tension foaming agent to add water the aqueous solution for being configured to that weight concentration is 0.5%, by the aqueous solution and nitrogen, air
Or the water injection well of the low-tension foam flooding described in natural gas mixing injection a step, injection rate is 0.3 times amount of formation pore body,
It is to calculate and control liquid, air volume ratio for 1 according to subsurface volume ratio that the aqueous solution is mixed with air：1, form foam flooding
Flow of oil, carries out low-tension foam flooding.
Embodiment 4：
Brij 35 carboxylate is substituted with myristyl alcohol polyethenoxy ether carboxylate, others were same as reality
Apply a 1-3.
Embodiment 5：
Brij 35 carboxylate is substituted with Brij 56 carboxylate, others were same as reality
Apply a 1-3.
Embodiment 6：
Brij 35 carboxylate is substituted with stearyl alcohol polyethenoxy ether carboxylate, others were same as reality
Apply a 1-3.
Embodiment 7：
Empgen BB is substituted with myristyl betaine, others were same as embodiment 1-6.
Embodiment 8：
Empgen BB is substituted with cetyl betaine, others were same as embodiment 1-6.
Embodiment 9：
Empgen BB is substituted with octadecyl betaine, others were same as embodiment 1-6.
Embodiment 10：
Air is substituted with nitrogen, others were same as embodiment 1-9.
Embodiment 11：
Substitute gas air is used, others were same as embodiment 1-9.
Claims (5)
1. the low-tension foaming agent of heterogeneous reservoir oil recovery factor is improved, it is characterised in that it is by the original of following weight percent proportioning
Material composition：
2. according to claim 1 improve heterogeneous reservoir oil recovery factor low-tension foaming agent, it is characterised in that described
Host be Brij 35 carboxylate, myristyl alcohol polyethenoxy ether carboxylate, cetyl alcohol gather
Oxygen ethene ether carboxylate, stearyl alcohol polyethenoxy ether carboxylate.
3. according to claim 1 improve heterogeneous reservoir oil recovery factor low-tension foaming agent, it is characterised in that described
Foam stabiliser be cocinic acid MEA.
4. according to claim 1 improve heterogeneous reservoir oil recovery factor low-tension foaming agent, it is characterised in that described
Alkyl betaine be empgen BB, myristyl betaine, cetyl betaine, octadecyl betaine.
5. the flooding method of the low-tension foaming agent of the raising heterogeneous reservoir oil recovery factor described in claim 1, its feature exists
Carried out in the flooding method as follows：
A. first take low-tension foaming agent to add water the aqueous solution for being configured to that weight concentration is 0.8～1.2%, quantity is formation pore volume
0.01～0.05 times amount, is then injected into implementing the water injection well of low-tension foam flooding, as preposed attributives；
B. take low-tension foaming agent to add water the aqueous solution for being configured to that weight concentration is 0.3～0.7%, by the aqueous solution and nitrogen,
The water injection well of the low-tension foam flooding described in air or natural gas mixing injection a step, injection rate be formation pore body 0.2～
0.4 times amount, it is to calculate and control liquid, gas according to subsurface volume ratio that the aqueous solution is mixed with nitrogen, air or natural gas
Product is than being 1：0.01～2, foam flooding fluid is formed, carries out low-tension foam flooding.
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| CN201510547631.XA CN106479470B (en) | 2015-08-31 | 2015-08-31 | Low-tension foaming agent for improving recovery ratio of crude oil of heterogeneous oil reservoir and oil displacement method |
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| CN201510547631.XA CN106479470B (en) | 2015-08-31 | 2015-08-31 | Low-tension foaming agent for improving recovery ratio of crude oil of heterogeneous oil reservoir and oil displacement method |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107880865A (en) * | 2017-11-01 | 2018-04-06 | 中国石油天然气股份有限公司 | A kind of low interfacial tension foam flooding finish and preparation method thereof |
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