CN105781511B - A kind of method of medium to high permeable oil reservoir volume increase - Google Patents
A kind of method of medium to high permeable oil reservoir volume increase Download PDFInfo
- Publication number
- CN105781511B CN105781511B CN201610109733.8A CN201610109733A CN105781511B CN 105781511 B CN105781511 B CN 105781511B CN 201610109733 A CN201610109733 A CN 201610109733A CN 105781511 B CN105781511 B CN 105781511B
- Authority
- CN
- China
- Prior art keywords
- well
- injection
- surfactant
- polymer
- water
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- 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
-
- 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Abstract
The invention belongs to technical field of tertiary oil recovery, and in particular to a kind of method of medium to high permeable oil reservoir volume increase, this method specifically include following steps：The screening of oil reservoir；Target reservoir polymer injection well is determined with note surfactant well；The injection stage of polymer；The injection stage of surfactant；The normal water filling stage；Field test results evaluation phase.The present invention has the characteristics that cost of investment is low and the degree of field test raising recovery ratio is high, and field test improves recovery ratio and is more than 15%, and input-output ratio is more than 1:5；The invention has the characteristics that technique simple, specific aim and workable.Therefore, present invention is generally applicable in the field test of medium to high permeable oil reservoir volume increase.
Description
Technical field
The invention belongs to technical field of tertiary oil recovery, and in particular to a kind of method of medium to high permeable oil reservoir volume increase.
Background technology
With the fast development of China's economy, the demand of oil is increasingly increased, short increasingly severe, and the mesh of oil
Preceding crude oil in China recovery percent of reserves less than 40%, remaining recoverable oil reserves is huge, particularly medium to high permeable oil reservoir, according to system
Meter, medium to high permeable oil reservoir resource account for more than the 60% of total resources, and medium to high permeable oil reservoir passes through long-term waterflooding development, contains to height
In the water interim later stage, production decline is serious, and stable yields difficulty is big, and therefore, there is an urgent need to new raising medium to high permeable oil recovery
Technology.
Medium to high permeable oil reservoir has formd local macropore, conventional water drive is difficult into one since long-period water drive is developed
Step improves recovery ratio, therefore, implements microbial oil displacement currently for middle and high infiltration oil reservoir and generally oil reservoir is carried out first with polymer
Tune is blocked up in deep, carries out surfactant flooding afterwards, the swept volume of oil reservoir is on the one hand improved using deep profile controlling, on the other hand profit
The displacement efficiency of oil reservoir is improved with chemical flooding.But this method is used in experiment block injection of polymer and surfactant and owned
The concurrently injected mode of well, different wells correspond to the oil reservoir of different permeabilities, therefore, inject the polymerization of the relatively low oil reservoir of permeability
On the other hand significantly thing causes the blocking of such oil reservoir, on the one hand causes the waste of polymer and biosurfactant,
Ground influences experiment block entirety recovery ratio degree.
The content of the invention
The purpose of the present invention is providing a kind of method of medium to high permeable oil reservoir volume increase in view of the deficiencies of the prior art, the party
Method determines polymer injection well and note surfactant well first；Secondly chemical polymerization thing is injected from polymer injection well, reached
Effective profile control effect；Again, chemical surfactant and CO are injected from note surfactant well2, the CO of injection2Can be effective
Ground improves the swept volume of chemical surfactant, and chemical surfactant improves the displacement efficiency of oil reservoir；Finally, from trial zone
Water flooding is injected in all water injection wells of block, further improves waterflooding effect, this method has specific aim and workable spy
Point, can not only effectively improve the field test results of medium to high permeable oil reservoir, and can be effectively reduced cost of investment, input production
Go out than high.
A kind of method of medium to high permeable oil reservoir volume increase, it is characterised in that specifically include following steps：
(1) screening of oil reservoir
The screening criteria of medium to high permeable oil reservoir is more than 1500 × 10 for reservoir temperature less than 80 DEG C, Reservoir Permeability-3μm2、
Viscosity of crude is less than 1200mPa.s and formation water salinity is less than 50000mg/L.
(2) target reservoir polymer injection well and note surfactant well determine
The water injection well of target reservoir is divided into polymer injection well and note surface-active by the size that pressure is injected according to water injection well
Agent well, the low well of water injection pressure are polymer injection well, and the high well of water injection pressure is to note surfactant well, polymer injection well
Quantity account for total water injection well quantity ratio be 30~50%, remaining well for note surfactant well.
(3) injection stage of polymer
Chemical polymerization thing is injected from polymer injection well, the total injection of chemical polymerization thing is 0.01~0.03PV, and note is poly-
The amount of compound well injection chemical polymerization thing accounts for the ratio-dependent of the total water injection rate of polymer injection well according to its water injection rate.
(4) injection stage of surfactant
After the completion of the injection stage of polymer, chemical surfactant and CO are injected from note surfactant well2, chemistry
The total injection of surfactant is 0.1~0.3PV, and the amount of note surfactant well injection chemical surfactant is noted according to it
Water accounts for the ratio-dependent of the note total water injection rate of surfactant well, CO2Injection rate and chemical surfactant injection rate ratio are
Mark gas liquid ratio 5~10 under condition:1.
(5) the normal water filling stage
Enter the normal water filling stage after the completion of the injection stage of surfactant, the water injection rate of every mouthful of water injection well is before testing
Water injection rate, field test terminates after normal water filling 12~24 months.
(6) field test results evaluation phase
After the completion of the normal water filling stage, calculate oil increment, improve recovery ratio degree and input-output ratio.
Preferably, the mass concentration of the chemical polymerization thing is 0.1~0.3%, molecular weight is 1~5 × 106。
Preferably, the chemical polymerization thing is polyacrylamide or polyethylene.
Preferably, the chemical surfactant is petroleum sulfonate or neopelex, mass concentration
For 0.2~0.5%.
The speed of the normal water filling of the water injection well is 30~200m3/d。
The characteristics of present invention is directed to medium to high permeable water-drive pool, is divided into polymer injection well and note surfactant by water injection well
Well；Secondly chemical polymerization thing is injected from polymer injection well, plays the role of effective profile control to oil reservoir；Again, from note surface
Chemical surfactant and CO are injected in activating agent well2, the CO of injection2Chemical surfactant can be effectively improved involves body
Product, the chemical surfactant of injection can effectively improve displacement efficiency；Finally, stratum is injected from experiment all water injection wells of block
Water, further improves waterflood efficiency, and this method has the characteristics that specific aim and workable, can not only effectively improve middle height
The field test results of oil reservoir are permeated, recovery ratio is improved and is more than 15%；And chemical polymerization thing and chemistry can be efficiently reduced
The dosage of surfactant, cost of investment is significantly less, and input-output ratio is high, more than 1:5.
Present invention has the advantages that：
(1) present invention have the characteristics that technique simply, specific aim and workable, be conducive to field popularization application；
(2) the applicable oil reservoir scope of the present invention is wide, is applicable not only to middle and high infiltration water-drive pool, is equally applicable to high temperature oil
Hide；
(3) present invention injects chemical surfactant using part well injection chemical polymerization thing and another part well
Method, this method can give full play to the respective profile control of injecting and washing oil function and the dosage for being effectively saved injecting, at the same time
The degree that field test improves recovery ratio is high, and field test improves recovery ratio and is more than 15%, and input-output ratio is more than 1:5.
Embodiment
The present invention is described in further detail with reference to specific embodiment, and with reference to data.It is to be understood that these embodiments
It is of the invention solely for the purpose of illustration, rather than limit the scope of the invention in any way.
Embodiment 1
Certain oil field block D, 68 DEG C, reservoir pressure 11.3MPa of reservoir temperature, porosity 38.9%, pore volume 7.2 ×
104m3, permeability 2700 × 10-3μm2, oil in place 3.5 × 104T, ground viscosity of crude 1150mPa.s, formation water salinity
For 15680mg/L, block average aqueous 96.3%, 12 mouthfuls of oil well, 6 mouthfuls of well, well water injection pressure and daily water-injection rate before experiment
It is shown in Table 1.Implement live oil displacement test in block D using the method for the present invention, specific implementation step is as follows：
The water injection pressure and daily water-injection rate of 1 block D wells of table
(1) screening of oil reservoir
The screening criteria of oil reservoir is more than 1500 × 10 for reservoir temperature less than 80 DEG C, Reservoir Permeability-3μm2, viscosity of crude
It is less than 50000mg/L less than 1200mPa.s and formation water salinity, block D meets the screening criteria of oil reservoir, can be in the block
Implement the present invention.
(2) target reservoir polymer injection well and note surfactant well determine
The water injection well of target reservoir is divided into by polymer injection well and note surface-active according to the size of injection pressure
Agent well, the low well of water injection pressure are polymer injection well, and the high well of water injection pressure is to note surfactant well, polymer injection well
Quantity account for total water injection well quantity ratio be 50%, be 3 mouthfuls, be respectively D2、D4And D6, the quantity of note surfactant well is 3
Mouthful, it is respectively D1、D3And D5。
(3) injection stage of polymer
Polyacrylamide is injected from polymer injection well, polyacrylamide molecular weight is 1~2 × 106, polyacrylamide
Mass concentration is 0.1%, the total injection of polyacrylamide is 0.01PV, is 720m3, polymer injection well injection polyacrylamide
Amount the ratio-dependent of the total water injection rate of polymer injection well, D are accounted for according to its water injection rate2、D4And D6It is total that well water injection rate accounts for polymer injection well
Water injection rate 330m3Ratio be respectively 95/330=28.8%, 110/330=33.3%, 125/330=37.9%, D2、D4With
D6The amount of well note polyacrylamide is respectively 720 × 28.8%=207.3m3, 720 × 33.3%=239.8m3With 720 ×
37.9%=272.9m3。
(4) injection stage of surfactant
After the completion of the injection stage of polymer, petroleum sulfonate and CO are injected from note surfactant well2, mahogany acid
Salt quality concentration is 0.2%, and the total injection of petroleum sulfonate is 0.2PV, is 1.44 × 104m3, polymer injection well injection oil
The amount of sulfonate accounts for the ratio-dependent of the total water injection rate of polymer injection well, D according to its water injection rate1、D3And D5Well water injection rate accounts for note oil
The total water injection rate 186m of sulfonic acid salt well3Ratio be respectively 72/186=38.7%, 46/186=24.7% and 68/186=
36.6%, D1、D3And D5The amount of well note petroleum sulfonate is respectively 1.44 × 104× 38.7%=5573m3、1.44×104×
24.7%=3557m3With 1.44 × 104× 36.6%=5270m3, CO2Injection rate and the injection rate ratio of petroleum sulfonate are
Mark gas liquid ratio 5 under condition:1, D1、D3And D5Well injects CO2Amount be respectively 2.7865 × 104Nm3(mark side), 1.7785 × 104Nm3
With 2.635 × 104Nm3。
(5) the normal water filling stage
Enter normal water filling stage, D after the completion of the injection stage of surfactant1、D2、D3、D4、D5、D6The water injection rate of well
It is respectively 72m for the water injection rate before experiment3、95m3、46m3、110m3、68m3And 125m3, scene examination after normal water filling 18 months
Test end.
(6) field test results evaluation phase
After the completion of the normal water filling stage, add up to increase oil 0.55 × 104T, improves recovery ratio 15.7%, input-output ratio 1:
5.8, aqueous to have dropped 9.0 percentage points, the present invention achieves obvious field test results in the block.
Embodiment 2
Certain oil field block E, 73 DEG C, reservoir pressure 13.5MPa of reservoir temperature, porosity 39.2%, pore volume 9.0 ×
104m3, permeability 3200 × 10-3μm2, oil in place 4.5 × 104T, ground viscosity of crude 1020mPa.s, formation water salinity
For 8650mg/L, block average aqueous 98.3% before experiment, 8 mouthfuls of oil well, 5 mouthfuls of well, well daily water-injection rate and water injection pressure are shown in
Table 2.Implement live oil displacement test in block B using the method for the present invention, specific implementation step is as follows：
The water injection pressure and daily water-injection rate of 2 block E wells of table
(1) screening of oil reservoir
The screening criteria of oil reservoir is more than 1000 × 10 for reservoir temperature less than 80 DEG C, Reservoir Permeability-3μm2, viscosity of crude
It is less than 50000mg/L less than 1200mPa.s and formation water salinity, block E meets the screening criteria of oil reservoir, can block reality
Apply the present invention.
(2) target reservoir polymer injection well and note surfactant well determine
The water injection well of target reservoir is divided into by polymer injection well and note surface-active according to the size of injection pressure
Agent well, the low well of water injection pressure are polymer injection well, and the high well of water injection pressure is to note surfactant well, polymer injection well
Quantity account for total water injection well quantity ratio be 40%, be 2 mouthfuls, be respectively E1And E4, the well quantity for noting surfactant is 3
Mouthful, it is respectively E2、E3And E5。
(3) injection stage of polymer
Polyethylene is injected from polymer injection well, molecular weight of polyethylene is 3~5 × 106, the mass concentration of polyethylene is
0.3%th, the total injection of polyethylene is 0.03PV, is 2700m3, the amount of polymer injection well injection polyethylene is according to its water injection rate
Account for the ratio-dependent of the total water injection rate of polymer injection well, E1And E4Well water injection rate accounts for the total water injection rate 220m of polymer injection well3Ratio point
Not Wei 120/220=54.5%, 100/220=45.5%, E1And E4The amount of well note polyethylene is respectively 2700 × 54.5%=
1472m3With 2700 × 45.5%=1228m3。
(4) injection stage of surfactant
After the completion of the injection stage of polymer, neopelex and CO are injected from note surfactant well2, ten
Dialkyl benzene sulfonic acids sodium mass concentration is 0.5%, and the total injection of neopelex is 0.10PV, is 9.0 × 103m3,
The amount of note surfactant well injection neopelex accounts for the note total water injection rate of surfactant well according to its water injection rate
Ratio-dependent, E2、E3And E5Well water injection rate accounts for the total water injection rate 210m of note surfactant well3Ratio be respectively 70/210=
33.3%th, 90/210=42.9% and 50/210=23.8%, E2、E3And E5Well note neopelex amount be respectively
9.0×103× 33.3%=2997m3、9.0×103× 42.9%=3861m3With 9.0 × 103× 23.8%=2142m3, CO2
Injection rate and the injection rate ratio of neopelex are gas liquid ratio 10 under mark condition:1, E2、E3And E5Well injects CO2Amount
Respectively 2.997 × 104Nm3、3.861×104Nm3With 2.142 × 104Nm3。
(5) the normal water filling stage
Enter normal water filling stage, E after the completion of the injection stage of surfactant1、E2、E3、E4、E5The water injection rate of well is examination
Water injection rate before testing, is respectively 120m3、70m3、90m3、100m3And 50m3, field test terminates after normal water filling 24 months.
(6) field test results evaluation phase
After the completion of the normal water filling stage, add up to increase oil 0.80 × 104T, improves recovery ratio 17.8%, input-output ratio 1:
6.2, aqueous to have dropped 10.3 percentage points, the present invention achieves obvious field test results in the block.
Embodiment 3
Certain oil field block G, 55 DEG C, reservoir pressure 13.2MPa of reservoir temperature, porosity 37.2%, pore volume 6.5 ×
104m3, permeability 2600 × 10-3μm2, oil in place 3.8 × 104T, ground viscosity of crude 850mPa.s, formation water salinity are
7560mg/L, block average aqueous 96.3% before experiment, 15 mouthfuls of oil well, 7 mouthfuls of well, well daily water-injection rate and water injection pressure are shown in Table
3.Implement live oil displacement test in block G using the method for the present invention, specific implementation step is as follows：
The day water and water injection pressure of 3 block G wells of table
(1) screening of oil reservoir
The screening criteria of oil reservoir is more than 1000 × 10 for reservoir temperature less than 80 DEG C, Reservoir Permeability-3μm2, viscosity of crude
It is less than 50000mg/L less than 1200mPa.s and formation water salinity, block G meets the screening criteria of oil reservoir, can be in this block
Implement the present invention.
(2) target reservoir polymer injection well and note surfactant well determine
The water injection well of target reservoir is divided into by polymer injection well and note surface-active according to the size of injection pressure
Agent well, the low well of water injection pressure are polymer injection well, and the high well of water injection pressure is to note surfactant well, polymer injection well
Quantity account for total water injection well quantity ratio be 30%, be 2 mouthfuls, be respectively G3And G5, note surfactant well quantity is 5 mouthfuls, point
Wei not G1、G2、G4、G6And G7。
(3) injection stage of polymer
Polyethylene is injected from polymer injection well, molecular weight of polyethylene is 2~3 × 106, the mass concentration of polyethylene is
0.2%th, the total injection of polyethylene is 0.02PV, is 1300m3, the amount of polymer injection well injection polyethylene is according to its water injection rate
Account for the ratio-dependent of the total water injection rate of polymer injection well, G3And G5Well water injection rate accounts for the total water injection rate 250m of polymer injection well3Ratio point
Wei not 130/250=52.0% and 120/250=48.0%, G3And G5The amount of well note polyethylene is respectively 1300 × 52.0%=
676m3With 1300 × 48.0%=624m3。
(4) injection stage of surfactant
After the completion of the injection stage of polymer, neopelex and CO are injected from note surfactant well2, ten
Dialkyl benzene sulfonic acids sodium mass concentration is 0.3%, and the total injection of neopelex is 0.3PV, is 1.95 × 104m3,
The amount of note surfactant well injection neopelex accounts for the note total water injection rate of surfactant well according to its water injection rate
Ratio-dependent, G1、G2、G4、G6And G7Well water injection rate accounts for the total water injection rate 405m of note surfactant well3Ratio be respectively 60/405
=14.8%, 105/405=25.9%, 80/405=19.8%, 90/405=22.2% and 70/405=17.3%, G1、G2、
G4、G6And G7The amount of well note neopelex is respectively 1.95 × 104× 14.8%=2886m3、1.95×104×
25.9%=5050m3、1.95×104× 19.8%=3861m3、1.95×104× 22.2%=4329m3With 1.95 × 104×
17.3%=3374m3, CO2Injection rate and the injection rate ratio of neopelex are gas liquid ratio 8 under mark condition:1, G1、G2、
G4、G6And G7Well injects CO2Amount be respectively 2.31 × 104Nm3、4.04×104Nm3、3.09×104Nm3、3.46×104Nm3With
2.70×104Nm3。
(5) the normal water filling stage
Enter normal water filling stage, G after the completion of the injection stage of surfactant1、G2、G3、G4、G5、G6And G7The note of well
Water is the water injection rate before experiment, is respectively 60m3、105m3、130m3、80m3、120m3、90m3And 70m3, normal water filling 12
Field test terminates after month.
(6) field test results evaluation phase
After the completion of the normal water filling stage, add up to increase oil 0.62 × 104T, improves recovery ratio 16.3%, input-output ratio 1:
7.3, aqueous to have dropped 12.8 percentage points, the present invention achieves obvious field test results in the block.
It is obvious to a person skilled in the art that the invention is not restricted to the details of above-mentioned one exemplary embodiment, Er Qie
In the case of without departing substantially from spirit or essential attributes of the invention, the present invention can be realized in other specific forms.Therefore, no matter
From the point of view of which point, the present embodiments are to be considered as illustrative and not restrictive, and the scope of the present invention is by appended power
Profit requires rather than described above limits, it is intended that all in the implication and scope of the equivalency of claim by falling
Change is included in the present invention.
Moreover, it will be appreciated that although the present specification is described in terms of embodiments, not each embodiment is only wrapped
Containing an independent technical solution, this narrating mode of specification is only that those skilled in the art should for clarity
Using specification as an entirety, the technical solutions in the various embodiments may also be suitably combined, forms those skilled in the art
It is appreciated that other embodiment.
Claims (4)
- A kind of 1. method of medium to high permeable oil reservoir volume increase, it is characterised in that specifically include following steps：(1) screening of oil reservoirThe screening criteria of medium to high permeable oil reservoir is more than 1500 × 10 for reservoir temperature less than 80 DEG C, Reservoir Permeability-3μm2, crude oil Viscosity is less than 1200mPa.s and formation water salinity is less than 50000mg/L；(2) target reservoir polymer injection well and note surfactant well determineThe water injection well of target reservoir is divided into polymer injection well and note surfactant well by the size that pressure is injected according to water injection well, The low well of water injection pressure is polymer injection well, and the high well of water injection pressure is to note surfactant well, the number of polymer injection well The ratio that amount accounts for total water injection well quantity is 30~50%, remaining well is note surfactant well；(3) injection stage of polymerInject chemical polymerization thing from polymer injection well, the total injection of chemical polymerization thing is 0.01~0.03PV, polymer injection The amount of well injection chemical polymerization thing accounts for the ratio-dependent of the total water injection rate of polymer injection well according to its water injection rate；(4) injection stage of surfactantAfter the completion of the injection stage of polymer, chemical surfactant and CO are injected from note surfactant well2, chemical surface The total injection of activating agent is 0.1~0.3PV, and the amount of note surfactant well injection chemical surfactant is according to its water injection rate Account for the ratio-dependent of the note total water injection rate of surfactant well, CO2Injection rate and chemical surfactant injection rate ratio are mark condition Lower gas liquid ratio 5~10:1；(5) the normal water filling stageEnter the normal water filling stage after the completion of the injection stage of surfactant, the water injection rate of every mouthful of water injection well is the note before experiment Water, field test terminates after normal water filling 12~24 months；(6) field test results evaluation phaseAfter the completion of the normal water filling stage, calculate oil increment, improve recovery ratio degree and input-output ratio.
- A kind of 2. method of medium to high permeable oil reservoir volume increase according to claim 1, it is characterised in that the chemical polymerization The mass concentration of thing is 0.1~0.3%, molecular weight is 1~5 × 106。
- A kind of 3. method of medium to high permeable oil reservoir volume increase according to claim 2, it is characterised in that the chemical polymerization Thing is polyacrylamide or polyethylene.
- A kind of 4. method of medium to high permeable oil reservoir volume increase according to claim 1, it is characterised in that the chemical surface Activating agent is petroleum sulfonate or neopelex, mass concentration are 0.2~0.5%.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610109733.8A CN105781511B (en) | 2016-02-29 | 2016-02-29 | A kind of method of medium to high permeable oil reservoir volume increase |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610109733.8A CN105781511B (en) | 2016-02-29 | 2016-02-29 | A kind of method of medium to high permeable oil reservoir volume increase |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN105781511A CN105781511A (en) | 2016-07-20 |
| CN105781511B true CN105781511B (en) | 2018-04-17 |
Family
ID=56402905
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201610109733.8A Active CN105781511B (en) | 2016-02-29 | 2016-02-29 | A kind of method of medium to high permeable oil reservoir volume increase |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN105781511B (en) |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107795306B (en) * | 2016-08-30 | 2020-03-27 | 中国石油化工股份有限公司 | Endogenous microbial oil recovery method for low-permeability oil reservoir |
Family Cites Families (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN1210490C (en) * | 2002-04-13 | 2005-07-13 | 大庆油田有限责任公司 | Method for increasing relative permeability of polymer injection well |
| CN1308569C (en) * | 2005-08-09 | 2007-04-04 | 诺信威(北京)科技发展有限公司 | Method of proceeding modulation design of oil field chemical oil driving equipment |
| AU2007286270A1 (en) * | 2006-08-10 | 2008-02-21 | Shell Internationale Research Maatschappij B.V. | Methods for producing oil and/or gas |
| CN201908638U (en) * | 2010-12-17 | 2011-07-27 | 中国石油天然气股份有限公司 | High-pressure small-displacement skid-mounted additive feeding device |
| EP2607607A1 (en) * | 2011-12-21 | 2013-06-26 | Welltec A/S | Stimulation method |
| CN102913233B (en) * | 2012-11-03 | 2015-02-04 | 中国石油大学(华东) | Method for recognizing dominant flow channel based on zero dimension comparison plate |
| CN104747149B (en) * | 2015-01-22 | 2016-04-06 | 中国石油大学(华东) | The detection method of passage is altered in the agent of binary combination flooding |
| CN104929597B (en) * | 2015-06-10 | 2019-02-15 | 中国石油天然气股份有限公司 | A kind of horizontal well chemical flooding recovery method |
-
2016
- 2016-02-29 CN CN201610109733.8A patent/CN105781511B/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CN105781511A (en) | 2016-07-20 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Wang et al. | Sweep improvement options for the Daqing oil field | |
| CN107365575B (en) | A kind of viscosity reduction oil displacement agent and oil displacement system suitable for heavy crude reservoir | |
| CN105626006B (en) | Low-permeability oil deposit CO2Drive technical limit well space and determine method | |
| CN105298438B (en) | More fine profile control methods in round polymer gel deep | |
| CN103224777A (en) | Weak base ternary composite reservoir oil displacement composition with formulated surfactant and application thereof | |
| US20140000886A1 (en) | Petroleum recovery process and system | |
| CN106867488A (en) | One kind physical crosslinking gel-like profile control and water plugging system and its application | |
| CN110242265A (en) | Original position receive-microballoon improve oil recovery factor filed application method | |
| CN105735952B (en) | A kind of method that medium to high permeable oil reservoir improves oil recovery factor | |
| CN105331348A (en) | Homogeneous-phase microemulsion oil-displacing agent applied to low-permeation oil field and preparation method of homogeneous-phase microemulsion oil-displacing agent | |
| US9702235B2 (en) | Method of improving mineral oil production by heating the formation and forming gel | |
| CN109233768A (en) | A kind of shutoff method of untraditional reservoir oil well | |
| US20140000884A1 (en) | Petroleum recovery process and system | |
| CN104895538A (en) | A method for increasing the strongly water-sensitive heavy oil reservoir recovery ratio | |
| CN106279526A (en) | A kind of gel micro-sphere system and preparation method thereof, gel micro-sphere dispersion, gel micro-sphere strengthening Polymer Flooding | |
| CN107338033A (en) | A kind of low-permeability sandstone oil reservoir Complex polymer type profile control agent and its application method | |
| CN105781511B (en) | A kind of method of medium to high permeable oil reservoir volume increase | |
| CN106967406A (en) | A kind of oil displacement system and flooding method for heterogeneous reservoir | |
| Qing et al. | Study and application of gelled foam for in-depth water shutoff in a fractured oil reservoir | |
| US20140000879A1 (en) | Petroleum recovery process and system | |
| CA2876214A1 (en) | Petroleum recovery process and system | |
| Yang et al. | Case study of alkali-polymer flooding with treated produced water | |
| Fjelde et al. | Improvement of Spontaneous Imbibition in Carbonate Rocks by CO²-saturated Brine | |
| CN104481478B (en) | Gather the method altered and its inorganic agent used in macropore plugging on polymer flooding correspondence oil well | |
| EP2568029A1 (en) | Method for transporting crude oil from subterranean crude oil storage areas |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| CB03 | Change of inventor or designer information | ||
| CB03 | Change of inventor or designer information |
Inventor after: Shi Shengnan Inventor after: Wang Xiaowei Inventor after: Zhao Ruqiang Inventor after: Yang Yizhi Inventor after: Lu Hui Inventor after: Ren Jiazheng Inventor after: Cao Jingjing Inventor after: Luo Huiqing Inventor after: Zhang Min Inventor after: Xu Dongdong Inventor after: Yu Qing Inventor after: Chen Chun Inventor after: Wang Yuxuan Inventor after: Li Lulu Inventor before: Liu Qin |
|
| GR01 | Patent grant | ||
| GR01 | Patent grant |