CN104675371B - It is a kind of it is poly- drive plus subsequent waterflooding after alternately inject gel and polymer solution complex oil displacing experimental method - Google Patents
It is a kind of it is poly- drive plus subsequent waterflooding after alternately inject gel and polymer solution complex oil displacing experimental method Download PDFInfo
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- CN104675371B CN104675371B CN201410810649.XA CN201410810649A CN104675371B CN 104675371 B CN104675371 B CN 104675371B CN 201410810649 A CN201410810649 A CN 201410810649A CN 104675371 B CN104675371 B CN 104675371B
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- 229920000642 polymer Polymers 0.000 title claims abstract description 39
- 238000002474 experimental method Methods 0.000 title claims abstract description 15
- 238000006073 displacement reaction Methods 0.000 claims abstract description 35
- 239000000243 solution Substances 0.000 claims abstract description 28
- 239000011435 rock Substances 0.000 claims abstract description 27
- 238000011084 recovery Methods 0.000 claims abstract description 26
- 239000007924 injection Substances 0.000 claims abstract description 22
- 238000002347 injection Methods 0.000 claims abstract description 22
- 238000000034 method Methods 0.000 claims abstract description 7
- 230000035699 permeability Effects 0.000 claims abstract description 6
- 239000003921 oil Substances 0.000 claims description 56
- 239000000499 gel Substances 0.000 claims description 27
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 22
- 239000007788 liquid Substances 0.000 claims description 11
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 8
- 238000004519 manufacturing process Methods 0.000 claims description 8
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 claims description 6
- 239000000853 adhesive Substances 0.000 claims description 6
- 230000001070 adhesive effect Effects 0.000 claims description 6
- 229920001971 elastomer Polymers 0.000 claims description 6
- 239000003822 epoxy resin Substances 0.000 claims description 5
- 229920000647 polyepoxide Polymers 0.000 claims description 5
- 239000006004 Quartz sand Substances 0.000 claims description 4
- 230000008569 process Effects 0.000 claims description 4
- PIICEJLVQHRZGT-UHFFFAOYSA-N Ethylenediamine Chemical compound NCCN PIICEJLVQHRZGT-UHFFFAOYSA-N 0.000 claims description 3
- 230000001965 increasing effect Effects 0.000 claims description 3
- 238000004088 simulation Methods 0.000 claims description 3
- 238000005266 casting Methods 0.000 claims description 2
- 229910001430 chromium ion Inorganic materials 0.000 claims description 2
- 238000001035 drying Methods 0.000 claims description 2
- 239000008398 formation water Substances 0.000 claims description 2
- 238000001879 gelation Methods 0.000 claims description 2
- 238000000465 moulding Methods 0.000 claims description 2
- 230000000149 penetrating effect Effects 0.000 claims description 2
- 229920002401 polyacrylamide Polymers 0.000 claims description 2
- 238000012545 processing Methods 0.000 claims description 2
- 239000010453 quartz Substances 0.000 claims description 2
- 230000033764 rhythmic process Effects 0.000 claims description 2
- 239000004576 sand Substances 0.000 claims description 2
- 238000012216 screening Methods 0.000 claims description 2
- BVPWJMCABCPUQY-UHFFFAOYSA-N 4-amino-5-chloro-2-methoxy-N-[1-(phenylmethyl)-4-piperidinyl]benzamide Chemical compound COC1=CC(N)=C(Cl)C=C1C(=O)NC1CCN(CC=2C=CC=CC=2)CC1 BVPWJMCABCPUQY-UHFFFAOYSA-N 0.000 claims 1
- 230000007062 hydrolysis Effects 0.000 claims 1
- 238000006460 hydrolysis reaction Methods 0.000 claims 1
- 239000012466 permeate Substances 0.000 claims 1
- 230000008859 change Effects 0.000 abstract description 4
- 238000000605 extraction Methods 0.000 abstract description 4
- 238000009826 distribution Methods 0.000 abstract description 2
- 230000000694 effects Effects 0.000 description 7
- 239000012267 brine Substances 0.000 description 4
- 230000011218 segmentation Effects 0.000 description 4
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 4
- 241000237858 Gastropoda Species 0.000 description 2
- 241000372132 Hydrometridae Species 0.000 description 2
- 239000013043 chemical agent Substances 0.000 description 2
- 239000002131 composite material Substances 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 238000009533 lab test Methods 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 229920006395 saturated elastomer Polymers 0.000 description 2
- 239000010865 sewage Substances 0.000 description 2
- 238000010008 shearing Methods 0.000 description 2
- 238000010521 absorption reaction Methods 0.000 description 1
- 239000012190 activator Substances 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 239000012752 auxiliary agent Substances 0.000 description 1
- 238000009412 basement excavation Methods 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000009792 diffusion process Methods 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000006260 foam Substances 0.000 description 1
- 239000003292 glue Substances 0.000 description 1
- 239000004519 grease Substances 0.000 description 1
- 238000003306 harvesting Methods 0.000 description 1
- 239000011229 interlayer Substances 0.000 description 1
- 244000005700 microbiome Species 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 239000006187 pill Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 230000002195 synergetic effect Effects 0.000 description 1
- 238000012360 testing method Methods 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
-
- 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
- E21B43/20—Displacing by water
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
- Colloid Chemistry (AREA)
Abstract
The present invention relates to the complex oil displacing experimental methods that gel and polymer solution are alternately injected after a kind of poly- drive plus subsequent waterflooding, are as follows：Step 1: preparing massive plate rock core first；Step 2: then carrying out poly- drive；Step 3: the alternately injection gel+polymer solution displacement of reservoir oil of more rounds；Step 4: subsequent waterflooding；Step 5: arranging data, ultimate recovery is calculated.The complex oil displacing experimental method of the present invention is on the basis of Remaining Oil Distribution after gathering drive and Reservoir Permeability change, seek to a kind of cost-effective method for excavating potentiality of remaining oil of subsequent waterflooding stage, recovery ratio is greatly improved, certain contribution is made that for actual oil extraction operation.
Description
Technical field
The present invention relates to chemical displacement of reservoir oil technical field, more particularly to it is a kind of it is poly- drive plus subsequent waterflooding after alternately injection gel and
The complex oil displacing experimental method of polymer solution.
Background technology
The serious oil reservoir of big and heterogeneity for permeability grade shifts to an earlier date water breakthrough, on moisture content there are oil well when water drive
The problems such as liter is very fast, and oil recovery factor is low.Polymer solution viscosity itself is higher, can be effectively improved water-oil mobility ratio, favorably
In alleviating interlayer contradiction, improve fluid entry profile, expands the swept volume of displacement liquid, to improve oil recovery factor.For this
Class oil reservoir can directly carry out polymer displacement of reservoir oil before water drive, to improve oilfield exploitation efficiency.Although polymer displacement of reservoir oil can be effective
The above-mentioned reservoir water drive problem is avoided, but underground still has 50% or so crude oil residual underground therefore to improve poly- after poly- drive
The recovery ratio for closing residual oil after object drives is particularly important.
The main reason for enhancing oil recovery in polymer flooding is limited is to alter poly- and subsequent waterflooding non-available water along macropore to follow
Ring phenomenon is serious, and the utilization rate of polymer is low, and middle hyposmosis position crude oil cannot get effective displacement.Tri compound is used after poly- drive
The drive technology displacement of reservoir oil remains to improve recovery ratio 10% or so, but the mixture of different component chemical agents is in reservoir of porous medium
The performance characteristics such as absorption, diffusion and migration differ greatly, lead to " the general effect of color " when the displacement of reservoir oil in reservoir pore and pay no attention to
" synergistic effect " thought, and all too many levels generate serious scale when use highly basic auxiliary agent, during extraction, influence oil well and normally give birth to
A series of problems, such as production, pump detection period shortens and Produced Liquid breaking emulsion and dewatering is difficult；Postpolymer flood carries out foam flooding again, harvesting
10%, but the guide-testing well-teams carried out in Oil Field can be improved in rate, and effect is undesirable and construction is complicated；Micro- life is used after poly- drive
The feasibility that object drives the method for further increasing recovery ratio has also carried out desk research, but indoor raising recovery ratio value is not high, and
Requirement of the microorganism to formation condition is harsher, and generalization is not strong.
Therefore, on the basis of Remaining Oil Distribution and Reservoir Permeability change after poly- drive, have through Ji after seeking poly- drive
The method of the excavation potentiality of remaining oil of effect is imperative.
Invention content
In view of above-mentioned analysis, the present invention is intended to provide alternately injection gel and polymer after a kind of poly- drive plus subsequent waterflooding
The complex oil displacing experimental method of solution, to solve the not high technical problem of existing oil recovery rate.
The purpose of the present invention is mainly achieved through the following technical solutions：
It is a kind of it is poly- drive plus subsequent waterflooding after alternately inject gel and polymer solution complex oil displacing experimental method, feature
It is, is as follows：
Step 1: preparing massive plate rock core first
1. using quartz content 99wt% or more quartz sand, screened again with vibration screening machine be 40-60 mesh, 60-100 mesh,
More than 100-200 mesh, 200 mesh four ranks；By E-44 epoxy resin, face dibatyl phithalate, ethylenediamine and acetone mixing
It is configured to adhesive；
2. preparing the quartz sand and adhesive of different ratio by several times, the natural rock that 20wt% is added after artificial stranding sand is heart-broken
Bits are packed into massive plate rock core mold, each pressurization 1 minute by several times；
It is dried 3. the massive plate rock core suppressed is placed in 100 DEG C of insulating box；
4. by the quadrangle of the massive plate rock core of drying and center cohesive end lid, the public affairs of a Φ 8mm are laid on each end cap
Button；
5. core surface is done frictioning processing, frictioning twice, prevents adhesive when casting from penetrating into rock core；
6. utilizing epoxy resin by rock core cast molding in a mold, massive plate rock core changes in positive rhythm, from top to bottom
Permeability is sequentially increased
Massive plate rock core size is long 600mm, wide 600mm, high 45mm；Chemical agent purity used be all chemistry it is pure with
On.
Step 2: then carrying out poly- drive, and calculate recovery ratio after poly- drive：
1. saturation water flooding simulated formation water salinity ranging from 6000mg/L~6400mg/ after massive plate rock core is evacuated
L measures the water phase permeability K of rock corewWith porosity Φw；
2. simulation oil is injected into rock core under 40 DEG C~50 DEG C of experimental temperature, until rock core outlet end does not have flow
Until going out, the initial oil saturation for measuring massive plate rock core is 52.92% (volume ratio, including moisture content is all volume later
Than)；
3. after injecting 0.56PV~0.64PV polymer, stop injection, carries out water drive to moisture content up to 97%~99%
Afterwards, stop displacement (wherein polymer be molecular weight 25,000,000, a concentration of 1200mg/L hydrolyzed polyacrylamide)；
4. in displacement process, record displacement velocity, time, oil production, water yield, pressure；
5. replacing graduated cylinder metering output liquid measure and oil mass every half an hour, measure moisture content, until moisture content reach 97%~
99%, pump is closed, and calculate recovery ratio after poly- drive.
Step 3: alternately being injected using the more rounds of 0.02PV~0.03PV gels+0.02PV~0.03PV polymer solutions
The displacement of reservoir oil, gel gelation time are 12h~for 24 hours, inject gel+round of the polymer solution displacement of reservoir oil 10~13 altogether, 0.40PV~
0.78PV, record alternately inject each round displacement velocity of each stage, the time, oil production, water yield, pressure (wherein gel be point
Son amount 25,000,000, polymer concentration 1800mg/L, poly- double ratio are 40:1 chromium ion gel rubber system).
Step 4: after subsequent waterflooding to moisture content is 97%~99% under the constant flow rate of 2~4mL/min, stop driving
It replaces；Displacement velocity, time, oil production, water yield, pressure are recorded in displacement process.
Step 5: arranging data, ultimate recovery is calculated.
Experiment heterogeneity massive plate core parameters used are as shown in table 1 below.
1 heterogeneity massive plate core parameters of table
Advantageous effect of the present invention：Since the present invention directly applies polymer to carry out the displacement of reservoir oil before water drive, can effectively avoid
The Character of Viscous Finger caused by grease viscosity differences slows down the rate of climb of moisture content；In addition in identical displacement hole
Under volume multiple (PV numbers), directly carry out carrying out the poly- recovery ratio driven, and displacement of reservoir oil time again after the poly- recovery ratio driven is higher than water drive
Short, oil recovery effect is good.
Other features and advantages of the present invention will illustrate in the following description, also, partial become from specification
It obtains it is clear that understand through the implementation of the invention.The purpose of the present invention and other advantages can be by the explanations write
Specifically noted structure is realized and is obtained in book, claims and attached drawing.
Description of the drawings
Attached drawing is only used for showing the purpose of specific embodiment, and is not considered as limitation of the present invention, in entire attached drawing
In, identical reference mark indicates identical component.
Change curves of the Fig. 1 between injected slurry volume and recovery ratio, pressure and moisture content.
Specific implementation mode
Specifically describing the preferred embodiment of the present invention below in conjunction with the accompanying drawings, wherein attached drawing constitutes the application part, and
It is used to illustrate the principle of the present invention together with embodiments of the present invention.
Embodiment one
(1) after the model cast being evacuated 6h, it is saturated artificial synthesized brine, measures porosity；
(2) model of the artificial synthesized brine of saturation is placed on constant temperature 12h or more in insulating box (45 DEG C)；
(3) oil is driven to until model is not discharged, and determines initial oil saturation；
(4) conventional sewage is used, 25,000,000 super high molecular weights, (viscosity is 40~50mPa.s to concentration 1200mg/L, and shearing is dilute
Release rear 20~25mPa.s of viscosity) prepare the polymer solution displacement of reservoir oil, injection rate 3mL/min, injection rate 0.60PV, it
Water drive calculates poly- drive+subsequent waterflooding recovery ratio to moisture content 98% afterwards；
(5) 0.03PV gel rubber system slugs are injected；
(6) the surfactant solution slug for injecting 0.03PV, records Liquid output and oil production；
(7) more round parallel laboratory tests are carried out according to experimental program and (5), (6) step.
According to experimental procedure, be initially injected the polymer solution 0.60PV displacement of reservoir oils, following injected water to it is aqueous reach 98% until,
Calculate oil recovery factor；Injection 0.03PV polymer solutions are filled in segmentation plug injection 0.03PV gel rubber system solution, correspondingly segmentation,
It is total to calculate the pressure after each composite slug injects and output liquid measure, until injection gel+polymer slug total amount reaches
Until 0.72PV；Following injected water measures output liquid measure and extraction oil mass, calculates recovery ratio to aqueous up to 98%.It is solidifying to evaluate
The oil displacement efficiency of glue profile control rear surface activator solution.
Embodiment two
(1) after the model cast being evacuated 6h, it is saturated artificial synthesized brine, measures porosity；
(2) model of the artificial synthesized brine of saturation is placed on constant temperature 12h or more in insulating box (45 DEG C)；
(3) oil is driven to until model is not discharged, and determines initial oil saturation；
(4) conventional sewage is used, 25,000,000 super high molecular weights, (viscosity is 40~50mPa.s to concentration 1200mg/L, and shearing is dilute
Release rear 20~25mPa.s of viscosity) prepare the polymer solution displacement of reservoir oil, injection rate 3mL/min, injection rate 0.64PV, it
Water drive calculates poly- drive recovery ratio to moisture content 98% afterwards；
(5) 0.02PV gel rubber system slugs are injected；
(6) polymer slug for injecting 0.02PV, records Liquid output and oil production；
(7) more round parallel laboratory tests are carried out according to experimental program and (5), (6) step.
According to experimental procedure, the injection of polymer solution 0.64PV displacement of reservoir oils, following injected water to it is aqueous reach 98% until, calculate
Oil recovery factor；Segmentation plug injection 0.02PV gel rubber system solution, correspondingly segmentation plug injection 0.02PV polymer solutions, calculate
Pressure after each composite slug injection and output liquid measure, until injection gel+polymer slug total amount is up to 0.44PV；
Following injected water measures output liquid measure and extraction oil mass, calculates recovery ratio to aqueous up to 99% or more.It is taken turns to compare pill more
The profile control effect of the profile control effect of secondary injection and the injection of big slug.
The foregoing is only a preferred embodiment of the present invention, but scope of protection of the present invention is not limited thereto,
Any one skilled in the art in the technical scope disclosed by the present invention, the change or replacement that can be readily occurred in,
It should be covered by the protection scope of the present invention.
Claims (5)
1. alternately injecting the complex oil displacing experimental method of gel and polymer solution after a kind of poly- drive plus subsequent waterflooding, feature exists
In being as follows：
Step 1: preparing massive plate rock core first；
Step 2: then carrying out poly- drive, and calculate recovery ratio after poly- drive；
Step 3: the alternately injection gel+polymer solution displacement of reservoir oil of more rounds；
Step 4: subsequent waterflooding；
Step 5: arranging data, ultimate recovery is calculated；
The step one specifically includes following step：
1. using the quartz sand of quartz content 99wt% or more, it is 40-60 mesh, 60-100 mesh, 100- to be screened again with vibration screening machine
More than 200 mesh, 200 mesh four ranks；By E-44 epoxy resin, face dibatyl phithalate, ethylenediamine and acetone mixed configuration
At adhesive；
2. preparing the quartz sand and adhesive of different ratio by several times, the natural core clast of 20wt% is added after artificial stranding sand, point
Secondary loading massive plate rock core mold, each pressurization 1 minute；
It is dried 3. the massive plate rock core suppressed is placed in 100 DEG C of insulating box；
4. by the quadrangle of the massive plate rock core of drying and center cohesive end lid, the pin thread of a Φ 8mm is laid on each end cap；
5. core surface is done frictioning processing, frictioning twice, prevents adhesive when casting from penetrating into rock core；
6. utilizing epoxy resin by rock core cast molding in a mold, massive plate rock core changes in positive rhythm, permeates from top to bottom
Rate is sequentially increased；
Alternately injection gel+polymer solution displacement of reservoir oil is more rounds：Using 0.01PV~0.03PV gels+0.02PV~
The alternately injection displacement of reservoir oils of the more rounds of 0.04PV polymer solutions, gel gelation time are 12h~for 24 hours, and it is molten to inject gel+polymer altogether
10~14 rounds of the liquid displacement of reservoir oil, 0.3PV~0.98PV, record alternately inject each round displacement velocity of each stage, time, oil-producing
Amount, water yield, pressure；
The step two specifically includes following step：
1. saturation simulation water flooding after massive plate rock core is evacuated, simulated formation water salinity ranging from 6000mg/L~
6400mg/L measures the water phase permeability K of rock corewWith porosity Φw；
2. simulation oil is injected into rock core under 40 DEG C~50 DEG C of experimental temperature, until rock core outlet end not there are flowing out for
Only, the initial oil saturation for measuring massive plate rock core is 52.92%；
3. after injecting 0.56PV~0.64PV polymer, stop injection, after carrying out subsequent waterflooding to moisture content to 97%, stops
Displacement；
4. in displacement process, record displacement velocity, time, oil production, water yield, pressure；
5. replacing graduated cylinder metering output liquid measure and oil mass every half an hour, moisture content is measured, until moisture content reaches 97%, closes pump,
And calculate recovery ratio after poly- drive.
2. alternately injecting the combination flooding of gel and polymer solution after a kind of poly- drive according to claim 1 plus subsequent waterflooding
Oily experimental method, which is characterized in that the E-44 epoxy resin, the purity for facing dibatyl phithalate, ethylenediamine and acetone
It is all more than chemistry is pure.
3. alternately injecting the combination flooding of gel and polymer solution after a kind of poly- drive according to claim 1 plus subsequent waterflooding
Oily experimental method, it is characterised in that：The polymer is the hydrolysis polyacrylamide of molecular weight 25,000,000, a concentration of 1200mg/L
Amine.
4. alternately injecting the combination flooding of gel and polymer solution after a kind of poly- drive according to claim 1 plus subsequent waterflooding
Oily experimental method, it is characterised in that：The gel is molecular weight 25,000,000, polymer concentration 1800mg/L, poly- double ratio are
40:1 chromium ion gel rubber system.
5. alternately injecting the combination flooding of gel and polymer solution after a kind of poly- drive according to claim 1 plus subsequent waterflooding
Oily experimental method, it is characterised in that：The subsequent waterflooding is, subsequent waterflooding is to aqueous under the constant flow rate of 2~4mL/min
After rate is 98%, stop displacement；Displacement velocity, time, oil production, water yield, pressure are recorded in displacement process.
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| CN105971572A (en) * | 2016-06-01 | 2016-09-28 | 中国海洋石油总公司 | Determination method for alternate injection opportunity of gel/polymer flooding |
| CN105863587B (en) * | 2016-06-01 | 2018-10-16 | 中国海洋石油集团有限公司 | A kind of determination method of polymer flooding alternating injection timing |
| CN106126829B (en) * | 2016-06-27 | 2019-01-04 | 西南石油大学 | A method of evaluation displacement of reservoir oil association polymer oil reservoir conformability |
| CN106050197B (en) * | 2016-07-21 | 2019-01-29 | 东北石油大学 | A kind of analysis method of Weak Base ASP Flood stimulation machanism |
| CN106639976A (en) * | 2017-02-15 | 2017-05-10 | 中海石油(中国)有限公司 | Simulation experiment method and device capable of increasing crude oil recovery ratio of multi-layer heterogeneous reservoir |
| CN108661612A (en) * | 2017-03-27 | 2018-10-16 | 中国石油化工股份有限公司 | A kind of method that high salinity reservoirs water drive improves recovery ratio |
| CN108267561B (en) * | 2017-12-25 | 2020-09-08 | 中国石油天然气股份有限公司 | Method and device for determining injection speed of indoor constant-speed experiment |
| CN109973061A (en) * | 2017-12-28 | 2019-07-05 | 东北石油大学 | A kind of three or three slug system of note |
| CN113236208A (en) * | 2021-04-20 | 2021-08-10 | 中海油能源发展股份有限公司 | Experimental device and method for physically simulating polymer flooding production liquid descending rule |
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2014
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|---|---|---|---|---|
| US3724546A (en) * | 1971-01-11 | 1973-04-03 | Chevron Res | Blood flood |
| CN1478850A (en) * | 2002-08-26 | 2004-03-03 | 大庆油田有限责任公司 | Method fo raising petroleum recovery ration using polymer solution dielement system |
| CN1664546A (en) * | 2005-03-30 | 2005-09-07 | 大庆石油学院 | Process for making quartz sand epoxy resin cementitious non-homogeneous model |
Non-Patent Citations (1)
| Title |
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| 聚合物驱后凝胶与二元复合体系段塞式交替注入驱油效果;王中国;《东北石油大学学报》;20120831;第36卷(第4期);54-58页 * |
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