CN104234677A - Method for improving condensate recovery ratio of condensate gas reservoir through gas injection vertical displacement - Google Patents
Method for improving condensate recovery ratio of condensate gas reservoir through gas injection vertical displacement Download PDFInfo
- Publication number
- CN104234677A CN104234677A CN201310240337.5A CN201310240337A CN104234677A CN 104234677 A CN104234677 A CN 104234677A CN 201310240337 A CN201310240337 A CN 201310240337A CN 104234677 A CN104234677 A CN 104234677A
- Authority
- CN
- China
- Prior art keywords
- gas
- well
- condensate
- injected
- injection
- 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.)
- Granted
Links
- 238000002347 injection Methods 0.000 title claims abstract description 34
- 239000007924 injection Substances 0.000 title claims abstract description 34
- 238000011084 recovery Methods 0.000 title claims abstract description 32
- 238000000034 method Methods 0.000 title claims abstract description 26
- 238000006073 displacement reaction Methods 0.000 title claims description 14
- 238000004519 manufacturing process Methods 0.000 claims abstract description 43
- 239000012530 fluid Substances 0.000 claims abstract description 10
- 230000008569 process Effects 0.000 claims abstract description 7
- 238000004458 analytical method Methods 0.000 claims abstract description 6
- 238000012937 correction Methods 0.000 claims abstract description 5
- 230000005484 gravity Effects 0.000 claims abstract description 5
- 230000004069 differentiation Effects 0.000 claims abstract description 4
- 238000002474 experimental method Methods 0.000 claims abstract description 3
- 230000015572 biosynthetic process Effects 0.000 claims description 6
- 238000007667 floating Methods 0.000 claims description 2
- 239000002245 particle Substances 0.000 claims description 2
- 238000005325 percolation Methods 0.000 claims description 2
- 230000035699 permeability Effects 0.000 claims description 2
- 230000009467 reduction Effects 0.000 claims description 2
- 238000011161 development Methods 0.000 abstract description 2
- 238000011549 displacement method Methods 0.000 abstract 1
- 230000000630 rising effect Effects 0.000 abstract 1
- 238000005065 mining Methods 0.000 description 8
- 230000000694 effects Effects 0.000 description 3
- 230000005012 migration Effects 0.000 description 3
- 238000013508 migration Methods 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 230000000704 physical effect Effects 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 238000009825 accumulation Methods 0.000 description 1
- 230000005465 channeling Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000009833 condensation Methods 0.000 description 1
- 230000005494 condensation Effects 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 238000005070 sampling Methods 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
Landscapes
- Separation By Low-Temperature Treatments (AREA)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
- Filling Or Discharging Of Gas Storage Vessels (AREA)
- Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)
Abstract
A gas injection vertical displacement method for improving condensate recovery ratio of a condensate gas reservoir belongs to the technical field of condensate gas field development; according to gas injection physical model experiments and production practice, when the density ratio of the preferred injected gas to the gas reservoir fluid is less than 0.75 under the stratum condition, the gravity differentiation phenomenon is obvious, and accordingly, the proper injected gas is selected; determining the position, perforation section, well type and well spacing of an injection and production well by adopting an injected gas infinitesimal body motion mechanical analysis method so as to better form an artificial gas cap in the gas injection process; determining the critical gas yield for preventing the gas-oil ratio from rising due to the injection gas coning according to a critical yield correction formula; the method can enable the injected gas to form an artificial gas cap at the high part of the structure and vertically displace the condensate gas downwards, so that the sweep coefficient of the injected gas is close to 100 percent, and the utilization rate of the injected gas and the final recovery ratio of the condensate oil can be obviously improved.
Description
Technical field
The present invention relates to the vertical displacement of a kind of gas injection and improve gas condensate reservoir condensate recovery ratio method, belong to development technique field, gas condensate field.
Background technology
Nineteen thirties colonial exploitation gas condensate reservoir, the initial stage adopts blowdown, and the forties progressively explores enforcement gas injecting mining; The production ratio U.S. of China's gas condensate reservoir is late more than 40 year, after eighties of last century early seventies starts to find the gas condensate reservoirs such as Sichuan anistree field, huge port slab bridge, Liaoning Panjin, Xinjiang Ke Keya, tooth Kazakhstan successively, just start starting; Initial stage gas condensate field substantially all adopts blowdown; Adopt in blowdown process in gas condensate field, strata pressure declines gradually, and when strata pressure is down to below dew-point pressure, reservoir fluid just retrograde condensation can occur, and separates out a large amount of condensate; Because the condensate of separating out is difficult to be plucked out of the ground, therefore adopt its condensate ultimate recovery of gas condensate field of blowdown lower, generally lower than 40%.
Current large-scale gas condensate field at home and abroad such as the Ty gas condensate field of Norway, Chinese tooth Kazakhstan, Ke Keya gas condensate field all use gas injecting mining, wherein the effect of gas injection mainly contains two, the first, supplements stratum energy, retentively stressor layer, reduces the precipitation of retrograde condensed liquid; The second, when strata pressure is down to below dew-point pressure, gas injection can be evaporated counter for condensed liquid, becomes the better gas phase of mobility, thus is more easily plucked out of; Condensate recovery ratio can be increased to about 50% by gas injecting mining.
Following problem is all there is in the gas condensate field adopting gas injecting mining:
1., in the gas condensate reservoir of current gas injecting mining, the sweep efficiency of injected gas on stratum is not high, and a large amount of injected gas arrives producing well shaft bottom too early, causes gas-oil ratio too high, have impact on the utilization rate of injected gas;
2. there is larger physical difference between injected gas and stratum condensate gas, current gas injecting mining mode does not consider the difference in physical properties of fluids, does not more consider to utilize this difference to increase gas injection swept volume, makes injected gas play larger effect;
3. conventional gas injecting mining can improve condensate recovery ratio more than 10 percentage points than blowdown, but still has a large amount of condensate to remain in underground in territory, injected gas bypassed area.
Summary of the invention
In order to overcome the deficiencies in the prior art, the invention provides the vertical displacement of a kind of gas injection and improving gas condensate reservoir condensate recovery ratio method.
The present invention aims to provide the vertical displacement of a kind of gas injection and improves gas condensate reservoir condensate recovery ratio method, effectively can prevent injecting dry gas and arrive producing well shaft bottom too early, and the physical difference of injected gas and stratum condensate gas and reservoir structural feature can be utilized to improve the sweep efficiency of injected gas, the ultimate recovery of condensate can be increased to more than 70%.
The vertical displacement of a kind of gas injection improves gas condensate reservoir condensate recovery ratio method, containing following steps;
According to gas injection physical model experiment and produce actual, preferred injected gas and gas reservoir fluid when density ratio is less than 0.75 under formation conditions gravitational differentiation phenomenon obvious, select suitable injected gas accordingly; Adopt injected gas micro unit dynamic analysis of motion method determination injection-production well position, perforated interval, well type and well spacing, artificial gas cap can better be formed in gas injection process; The critical gas production preventing from causing gas-oil ratio to rise owing to injecting gas coning is determined according to critical output correction formula; The method can make injected gas form artificial gas cap and displacement condensate gas vertically downward in structure high-order bit, makes the sweep efficiency of injected gas close to 100%, can significantly improve the utilization rate of injected gas and the ultimate recovery of condensate.
Carry out dynamic analysis of motion to injected gas micro unit, gravity suffered by micro unit is G, and buoyancy is F
floating, the difference of the buoyancy vertically upward its gravity vertically downward and fluid density contrast produced is defined as barometric gradient dp vertically upward
1/ dL
1, then on micro unit, barometric gradient is:
Carry out particle process to micro unit, then micro unit place barometric gradient is:
Injected gas micro unit in the horizontal direction pressure reduction is Δ p, pressure differential deltap p ' vertically upward; Again in conjunction with percolation hydraulic theory, just can obtain t injected gas micro unit in the horizontal direction, vertical direction top offset:
To enable injected gas form artificial gas cap at gas reservoir structure top smoothly, need meet when the horizontal movement of injected gas micro unit reaches 1/2nd injector producer distances, its vertical direction top offset should be not less than the distance between perforated interval top to reservoir top, makes D
perforationrepresent the distance of perforated interval top to structural high, namely need to meet and work as S
level=0.5D
note is adoptedtime, S
vertically≮ D
perforation; If straight well can not meet this condition, can horizontal well gas-injection be changed into, and make horizontal segment direction vertical with injection-production well line direction, to reduce the lateral pressure difference that gas injection causes, reduce the horizontal movement speed of injected gas; Injected gas so just can be enable to form artificial gas cap at gas reservoir structure top well;
After formation artificial gas cap, to when having a condensate gas reservoir of injected gas pneumatic jack, need the flow performance taking into full account top injected gas, choose reasonable producing well perforating site and output, thus prevent injecting gas coning and cause production gas-oil ratio to raise; Utilizing barometric gradient method of comparison to set up anti-injected gas pneumatic jack bores into critical output calculating correction formula;
Injected gas bottom definition artificial gas cap and the density variation of condensate gas and the barometric gradient that produces is dp
2/ dL
2; Make dp
2/ dL
2equal gas well with the barometric gradient produced bottom pneumatic jack during certain yield production, to suppose bottom injected gas pneumatic jack with the distance at this gas recovery well perforated interval top to be D, the critical gas production Q preventing from causing gas-oil ratio to rise owing to injecting gas coning can be obtained
critical;
Gas recovery well gas production need be met during production and be less than Q
critical; When the critical gas production of straight well is less than 0.2 with the ratio of open-flow capacity, with be less than critical gas production produce cannot Appropriate application gas well deliverability time, straight well is changed into horizontal well to produce, and make horizontal segment direction vertical with injection-production well line direction, when making gas well with identical yield production, produce less pressure drop in shaft bottom;
Above Q
critical-critical output, m
3/ d;
The distance of D-between perforated interval top and gas reservoir structural high, m;
D
pneumatic jack is thickdistance bottom-injected gas pneumatic jack and between gas reservoir structural high, m;
H
always-injected gas and condensate gas gross thickness, m;
K
verticallythe vertical permeability of-condensate gas, D;
μ
injected gasthe viscosity of-injected gas, mPas;
B
injected gasthe volume factor of-injected gas, m
3/ m
3;
R
ethe earial drainage radius of-gas well, m;
R
wthe well radius of-gas well, m.
Advantage of the present invention is the gravitational differentiation utilizing gas density difference to be formed, and form injected gas pneumatic jack in reservoir high-order bit, realize vertical displacement by the expansion of injected gas pneumatic jack, the method can significantly improve the utilization rate of injected gas and the ultimate recovery of condensate.
Accompanying drawing explanation
When considered in conjunction with the accompanying drawings, by referring to detailed description below, more completely can understand the present invention better and easily learn wherein many adjoint advantages; But accompanying drawing described herein is used to provide a further understanding of the present invention, form a part of the present invention; Schematic description and description of the present invention, for explaining the present invention, does not form inappropriate limitation of the present invention, as schemed wherein:
Fig. 1 injected gas micro unit dynamic analysis of motion schematic diagram;
Fig. 2 is for injecting dry gas migration rule schematic diagram;
Fig. 3 is gas reservoir vertical depth of the present invention and vertical depth point above gas reservoir voids volume graph of relation;
Fig. 4 is that D well vertical depth of the present invention and MDT test gas-oil ratio and to cross figure;
Fig. 5 is producing well perforating site optimization figure.
Below in conjunction with drawings and Examples, the present invention is further described.
Detailed description of the invention
Obviously, the many modifications and variations that those skilled in the art do based on aim of the present invention belong to protection scope of the present invention.
Embodiment 1: as shown in Figure 1, Figure 2, shown in Fig. 3, Fig. 4 and Fig. 5, the vertical displacement of a kind of gas injection improves gas condensate reservoir condensate recovery ratio method,
For the above three large problems adopting gas injecting mining gas condensate reservoir, the vertical displacement of a kind of gas injection is provided to improve gas condensate reservoir condensate recovery ratio method; The method can physical properties of fluids difference between Appropriate application injected gas and stratum condensate gas, improves injected gas sweep efficiency in the earth formation and effectively can reduce the generation of has channeling, finally can significantly improve the ultimate recovery of injected gas utilization rate and condensate.
For certain gas reservoir one injection-production well group Y, this injection-production well group has a bite gas injection well A well at present, and two mouthfuls of producing wells lay respectively at the B well of its eastern 600m and the C well of western 580m; Analyze injected gas motion conditions between gas injection well A well and gas recovery well B well, gas injection well flowing bottomhole pressure (FBHP) is 47.1MPa, and gas recovery well flowing bottomhole pressure (FBHP) is 43.3MPa; Its structure top forms artificial gas cap at present, now for closing A well, utilizes this technology to redesign injection-production program to this injection-production well group, forms North and South direction one note one and adopts well group production; According to gas reservoir engineering research, this injection-production well group major parameter is as follows: ρ
inject gas=246.3kg/m
3, ρ
condensate gas=349.6kg/m
3, K
level=183mD, K
vertically=61mD, Z
injected gas=1.26, Z
condensate gas=1.38, B
injected gas=3.7368 × 10
-3m
3/ (mark) m
3, B
condensate gas=3.4363 × 10
-3m
3/ (mark) m
3, μ
injected gas=0.0156mPas, μ
condensate gas=0.0172mPas, h
always=50m, r
e=462m, r
w=0.1m;
Cut-off footpath is the dry gas micro unit of L is research object, as Fig. 1; Barometric gradient vertically upward suffered by it is:
T injected gas micro unit in the horizontal direction, vertical direction displacement:
Need meet and work as S
level=0.5D
note is adoptedtime, S
vertically≮ D
perforation; The injector producer distance of A JingBJing is 600m, i.e. S
level=0.5 × 600=300m, then injected gas is from gas injection well migration to time t=4 × 10 required for 1/2nd injector producer distances
6s, within this time, injected gas in the vertical migration distance is S
vertically=0.4 × 10
-5× 4 × 10
6=16m, namely needs to ensure that gas injection well perforated interval and gas reservoir structural high distance are no more than 16m.
In conjunction with this injection-production well group practical condition, determine to close gas injection well A well, arrange a gas recovery well D at A well Nan560mChu, arrange a gas injection well E at A well Bei520mChu;
According to Y injection-production well group geologic feature, calculate the gas reservoir voids volume of more than different vertical depth this vertical depth point corresponding, and the relation curve both setting up, as Fig. 3;
Calculate the accumulation injected gas volume 3.8 × 10 of gas injection well A well
8m
3, conversion to formation condition lower volume is:
Can find from Fig. 3, the corresponding gas reservoir vertical depth of this value is 4166.5m, and namely on height above sea level-4166.5m puts, region is injected gas gas cap region;
In the drilling process of gas recovery well D well, carry out MDT sampling at reservoir different depth, obtain the gas-oil ratio change curve of the different vertical depth of gas reservoir, as Fig. 4;
At vertical depth 4165m place, fluid gas-oil ratio is 2805m
3/ m
3, can judge that this place's fluid is rich in condensate, belong to rich gas; Under vertical depth 4165m, gas-oil ratio is from 2805 m
3/ m
3, be reduced to 1665 m gradually
3/ m
3, condensate content increases with vertical depth and increases gradually; And on vertical depth 4165m, gas-oil ratio is rapidly increased to 95000 m
3/ m
3; Only higher than the 4166.7m place of 4165m place 1.7m, gas-oil ratio just reaches 7000m
3/ m
3, show as the feature of injected gas, therefore can judge that this well vertical depth 4165m to 4166.7m locates existence one mixed zone, be exactly injected gas pneumatic jack district on this mixed zone, its injected gas pneumatic jack thickness D
pneumatic jack is thickat about 15m;
Determine injected gas pneumatic jack interface injected gas and condensate gas density variation and the barometric gradient dp produced
2/ dL
2;
In order value equal gas well with during certain yield production in the barometric gradient that injected gas pneumatic jack interface place produces; This gas reservoir gas-bearing net pay 50m, injected gas pneumatic jack thickness 15m, then prevent the critical gas production Q owing to injecting gas coning
criticalas follows:
Change D value, corresponding Q can be obtained
critical, gas recovery well gas production need be met during production and be less than Q
critical, as Fig. 5; When the critical gas production of straight well is less than 0.2 with the ratio of open-flow capacity, with be less than critical gas production produce cannot Appropriate application gas well deliverability time, straight well is changed into horizontal well to produce, and make horizontal segment direction vertical with injection-production well line direction, when making gas recovery well with identical yield production, produce less pressure drop in shaft bottom.
Attached: when gas recovery well is horizontal well, solving corresponding critical gas production only needs the air feed radius r in above formula
echange the equivalent air feed radius r of horizontal well
ed; Make horizontal well drive area to be S, horizontal section length is L, then have:
As mentioned above, embodiments of the invention are explained, but as long as do not depart from inventive point of the present invention in fact and effect can have a lot of distortion, this will be readily apparent to persons skilled in the art; Therefore, such variation is also all included within protection scope of the present invention.
Claims (2)
1. the vertical displacement of gas injection improves a gas condensate reservoir condensate recovery ratio method, it is characterized in that containing following steps;
According to gas injection physical model experiment and produce actual, preferred injected gas and gas reservoir fluid when density ratio is less than 0.75 under formation conditions gravitational differentiation phenomenon obvious, select suitable injected gas accordingly; Adopt injected gas micro unit dynamic analysis of motion method determination injection-production well position, perforated interval, well type and well spacing, can better artificial gas cap be formed in gas injection process; The critical gas production preventing from causing gas-oil ratio to rise owing to injecting gas coning is determined according to critical output correction formula; Make injected gas form artificial gas cap and displacement condensate gas vertically downward in structure high-order bit, make the sweep efficiency of injected gas close to 100%, improve the utilization rate of injected gas and the ultimate recovery of condensate.
2. the vertical displacement of a kind of gas injection according to claim 1 improves gas condensate reservoir condensate recovery ratio method, it is characterized in that containing following steps;
Carry out dynamic analysis of motion to injected gas micro unit, gravity suffered by micro unit is G, and buoyancy is F
floating, the difference of the buoyancy vertically upward its gravity vertically downward and fluid density contrast produced is defined as barometric gradient dp vertically upward
1/ dL
1, then on micro unit, barometric gradient is:
Carry out particle process to micro unit, then micro unit place barometric gradient is:
Injected gas micro unit in the horizontal direction pressure reduction is Δ p, pressure differential deltap p ' vertically upward; Again in conjunction with percolation hydraulic theory, just can obtain t injected gas micro unit in the horizontal direction, vertical direction top offset:
To enable injected gas form artificial gas cap at gas reservoir structure top smoothly, need meet when the horizontal movement of injected gas micro unit reaches 1/2nd injector producer distances, its vertical direction top offset should be not less than the distance between perforated interval top to reservoir top, makes D
perforationrepresent the distance of perforated interval top to structural high, namely need to meet and work as S
level=0.5D
note is adoptedtime, S
vertically≮ D
perforation; If straight well can not meet this condition, can horizontal well gas-injection be changed into, and make horizontal segment direction vertical with injection-production well line direction, to reduce the lateral pressure difference that gas injection causes, reduce the horizontal movement speed of injected gas; Injected gas so just can be enable to form artificial gas cap at gas reservoir structure top well;
After formation artificial gas cap, to when having a condensate gas reservoir of injected gas pneumatic jack, need the flow performance taking into full account top injected gas, choose reasonable producing well perforating site and output, thus prevent injecting gas coning and cause production gas-oil ratio to raise; Utilize barometric gradient method of comparison to set up critical output and calculate correction formula;
Injected gas bottom definition artificial gas cap and the density variation of condensate gas and the barometric gradient that produces is dp
2/ dL
2; Make dp
2/ dL
2equal gas well with the barometric gradient produced bottom pneumatic jack during certain yield production, to suppose bottom injected gas pneumatic jack with the distance at this gas recovery well perforated interval top to be D, can obtain preventing the critical gas production Q owing to injecting gas coning and then causing gas-oil ratio to rise
critical;
Gas recovery well gas production need be met during production and be less than Q
critical; When the critical gas production of straight well is less than 0.2 with the ratio of open-flow capacity, with be less than critical gas production produce cannot Appropriate application gas well deliverability time, straight well is changed into horizontal well to produce, and make horizontal segment direction vertical with injection-production well line direction, when making gas recovery well with identical yield production, produce less pressure drop in shaft bottom;
Above Q
critical-critical output, m
3/ d;
The distance of D-between perforated interval top and gas reservoir structural high, m;
D
pneumatic jack is thickdistance bottom-injected gas pneumatic jack and between gas reservoir structural high, m;
H
always-injected gas and condensate gas gross thickness, m;
K
verticallythe vertical permeability of-condensate gas, D;
μ
injected gasthe viscosity of-injected gas, mPas;
B
injected gasthe volume factor of-injected gas, m
3/ m
3;
R
ethe earial drainage radius of-gas well, m;
R
wthe well radius of-gas well, m.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201310240337.5A CN104234677B (en) | 2013-06-18 | 2013-06-18 | Method for improving condensate recovery ratio of condensate gas reservoir through gas injection vertical displacement |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201310240337.5A CN104234677B (en) | 2013-06-18 | 2013-06-18 | Method for improving condensate recovery ratio of condensate gas reservoir through gas injection vertical displacement |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN104234677A true CN104234677A (en) | 2014-12-24 |
| CN104234677B CN104234677B (en) | 2016-12-28 |
Family
ID=52223484
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201310240337.5A Active CN104234677B (en) | 2013-06-18 | 2013-06-18 | Method for improving condensate recovery ratio of condensate gas reservoir through gas injection vertical displacement |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN104234677B (en) |
Cited By (14)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN104563982A (en) * | 2015-01-06 | 2015-04-29 | 西南石油大学 | High-temperature high-pressure dry gas injection longitudinal wave and efficiency testing device and method for gas condensate reservoir |
| CN106499371A (en) * | 2015-09-06 | 2017-03-15 | 中国石油天然气股份有限公司 | Method and device for improving recovery ratio of condensate oil gas reservoir through single-well circulating gas injection |
| CN106934084A (en) * | 2015-12-30 | 2017-07-07 | 中国石油天然气股份有限公司 | Phase state fitting method for condensate gas reservoir with bottom oil |
| CN107288590A (en) * | 2016-04-11 | 2017-10-24 | 中国石油化工股份有限公司 | One kind note CO2Improve the experimental method of Recovery of Gas Condensate Reservoirs |
| CN107620587A (en) * | 2017-10-30 | 2018-01-23 | 中国石油化工股份有限公司 | The control method of the vaporific retrograde condensation of gas condensate reservoir |
| CN108442906A (en) * | 2018-04-26 | 2018-08-24 | 中国石油天然气股份有限公司 | Steam huff and puff heavy oil reservoir perforating method and perforating structure |
| CN110284860A (en) * | 2019-07-19 | 2019-09-27 | 中国石油化工股份有限公司 | Blocky thick-layer sandstone oil reservoir note adopts interactive artificial inclination angle CO2Flooding method |
| CN110714742A (en) * | 2018-07-12 | 2020-01-21 | 中国石油化工股份有限公司 | Method for improving recovery ratio of bottom water condensate gas reservoir |
| CN111472764A (en) * | 2020-04-13 | 2020-07-31 | 西南石油大学 | Method for calculating recovery rate of rich gas in rich gas flooding process |
| CN113250659A (en) * | 2020-02-13 | 2021-08-13 | 中国石油天然气股份有限公司 | Gas injection experiment simulation method and device for improving displacement efficiency |
| CN113404486A (en) * | 2020-03-17 | 2021-09-17 | 中国石油天然气股份有限公司 | Method and device for determining movement speed of fluid interface of condensate gas cap oil reservoir |
| CN115653554A (en) * | 2022-08-17 | 2023-01-31 | 西南石油大学 | Micro-experiment method for removing retrograde condensation injury through gas injection based on micro-fluidic control |
| CN115898345A (en) * | 2021-08-06 | 2023-04-04 | 中国石油天然气股份有限公司 | Carbon dioxide-containing gas reservoir development system |
| CN117077574A (en) * | 2023-10-16 | 2023-11-17 | 西安石油大学 | Quantitative characterization method and device for displacement mechanism of fracture-cavity oil reservoir model |
Family Cites Families (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5720350A (en) * | 1996-05-03 | 1998-02-24 | Atlantic Richfield Company | Method for recovering oil from a gravity drainage formation |
| CN102767357A (en) * | 2012-07-26 | 2012-11-07 | 中国石油大学(北京) | V-shaped well for gas-cap reservoir |
| CN102839951B (en) * | 2012-09-11 | 2015-05-06 | 中国石油天然气股份有限公司 | Production string for rhythm oil layer gravity gas drive and method thereof |
-
2013
- 2013-06-18 CN CN201310240337.5A patent/CN104234677B/en active Active
Cited By (21)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN104563982B (en) * | 2015-01-06 | 2017-02-01 | 西南石油大学 | High-temperature high-pressure dry gas injection longitudinal wave and efficiency testing device and method for gas condensate reservoir |
| CN104563982A (en) * | 2015-01-06 | 2015-04-29 | 西南石油大学 | High-temperature high-pressure dry gas injection longitudinal wave and efficiency testing device and method for gas condensate reservoir |
| CN106499371A (en) * | 2015-09-06 | 2017-03-15 | 中国石油天然气股份有限公司 | Method and device for improving recovery ratio of condensate oil gas reservoir through single-well circulating gas injection |
| CN106934084A (en) * | 2015-12-30 | 2017-07-07 | 中国石油天然气股份有限公司 | Phase state fitting method for condensate gas reservoir with bottom oil |
| CN107288590B (en) * | 2016-04-11 | 2019-05-07 | 中国石油化工股份有限公司 | A kind of note CO2Improve the experimental method of Recovery of Gas Condensate Reservoirs |
| CN107288590A (en) * | 2016-04-11 | 2017-10-24 | 中国石油化工股份有限公司 | One kind note CO2Improve the experimental method of Recovery of Gas Condensate Reservoirs |
| CN107620587A (en) * | 2017-10-30 | 2018-01-23 | 中国石油化工股份有限公司 | The control method of the vaporific retrograde condensation of gas condensate reservoir |
| CN108442906A (en) * | 2018-04-26 | 2018-08-24 | 中国石油天然气股份有限公司 | Steam huff and puff heavy oil reservoir perforating method and perforating structure |
| CN110714742A (en) * | 2018-07-12 | 2020-01-21 | 中国石油化工股份有限公司 | Method for improving recovery ratio of bottom water condensate gas reservoir |
| CN110714742B (en) * | 2018-07-12 | 2021-11-09 | 中国石油化工股份有限公司 | Method for improving recovery ratio of bottom water condensate gas reservoir |
| CN110284860A (en) * | 2019-07-19 | 2019-09-27 | 中国石油化工股份有限公司 | Blocky thick-layer sandstone oil reservoir note adopts interactive artificial inclination angle CO2Flooding method |
| CN110284860B (en) * | 2019-07-19 | 2021-07-06 | 中国石油化工股份有限公司 | Interactive artificial dip angle CO is adopted to cubic thick-layer sandstone oil reservoir notes2Oil displacement method |
| CN113250659A (en) * | 2020-02-13 | 2021-08-13 | 中国石油天然气股份有限公司 | Gas injection experiment simulation method and device for improving displacement efficiency |
| CN113404486B (en) * | 2020-03-17 | 2023-12-22 | 中国石油天然气股份有限公司 | Method and device for determining movement speed of fluid interface of condensate gas cap oil reservoir |
| CN113404486A (en) * | 2020-03-17 | 2021-09-17 | 中国石油天然气股份有限公司 | Method and device for determining movement speed of fluid interface of condensate gas cap oil reservoir |
| CN111472764A (en) * | 2020-04-13 | 2020-07-31 | 西南石油大学 | Method for calculating recovery rate of rich gas in rich gas flooding process |
| CN111472764B (en) * | 2020-04-13 | 2022-04-29 | 西南石油大学 | Method for calculating recovery rate of rich gas in rich gas flooding process |
| CN115898345A (en) * | 2021-08-06 | 2023-04-04 | 中国石油天然气股份有限公司 | Carbon dioxide-containing gas reservoir development system |
| CN115653554A (en) * | 2022-08-17 | 2023-01-31 | 西南石油大学 | Micro-experiment method for removing retrograde condensation injury through gas injection based on micro-fluidic control |
| CN117077574A (en) * | 2023-10-16 | 2023-11-17 | 西安石油大学 | Quantitative characterization method and device for displacement mechanism of fracture-cavity oil reservoir model |
| CN117077574B (en) * | 2023-10-16 | 2024-02-23 | 西安石油大学 | Quantitative characterization method and device for displacement mechanism of fracture-cavity oil reservoir model |
Also Published As
| Publication number | Publication date |
|---|---|
| CN104234677B (en) | 2016-12-28 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN104234677B (en) | Method for improving condensate recovery ratio of condensate gas reservoir through gas injection vertical displacement | |
| CN105888630B (en) | Method for improving recovery efficiency by huff-puff oil recovery of tight oil fracturing horizontal well | |
| CN105114048B (en) | A kind of staged fracturing of horizontal well single-well injection-production oil production method | |
| CN110397428B (en) | Displacement coalbed methane yield increasing method for coalbed methane jointly mined by vertical well and U-shaped butt well | |
| CN103046910B (en) | Water drive development method for oil reservoir in ultrahigh water cut period | |
| CN102777157B (en) | CO2 drive oil-gas-water separate well injecting oil reservoir mixing drive development method | |
| CN110425003B (en) | Mining method for improving recovery ratio of coal bed gas in coal bed gas development vertical well and directional well group | |
| CN101876241B (en) | Method for improving water drive recovery ratio of positive rhythm thick oil layer | |
| CN104594872A (en) | Method for optimizing fracture conductivity of tight gas-reservoir fractured horizontal well | |
| CN107218024B (en) | Method for adjusting rhombus inverted nine-point well pattern in high water-cut period of multilayer low-permeability sandstone oil reservoir | |
| CN103174403A (en) | Gravity and steam flooding combined mining method for thick-layer interlayer-containing common heavy oil reservoir | |
| CN104895541B (en) | Method for breaking interlayer in oil layer during double-horizontal-well SAGD exploitation | |
| CN107630686B (en) | compact oil energy supplementing method for staggered displacement and imbibition displacement between horizontal well sections | |
| CN103939069A (en) | Steam-gas displacement and gravity oil drain composite exploiting method | |
| CN109209306A (en) | Horizontal well CO injection for ultra-low permeability tight oil reservoir2Asynchronous throughput energy supplementing method | |
| CN112610191B (en) | Method for exploiting natural gas hydrate reservoir permeable by cover layer by utilizing branch horizontal well | |
| CN110259421B (en) | Fractured compact oil reservoir water injection energy supplementing method | |
| CN107832540A (en) | A kind of compact oil reservoir technical limit well space determines method | |
| CN106437642A (en) | Injection-production asynchronous mining method for horizontal well of fractured reservoir | |
| CN104929597B (en) | Chemical flooding exploitation method for horizontal well | |
| CN104405349A (en) | Method for improving water-flooding development effect of bottom water reservoir by utilizing multistage high-pressure water jet | |
| CN110306965A (en) | A kind of method for increasing for coal bed gas low yield wellblock | |
| CN109025940A (en) | A kind of CO for compact oil reservoir2Pressure break displacement of reservoir oil integration oil production method | |
| CN104975826A (en) | Method for improving recovery ratio of super heavy oil reservoir | |
| CN104847302A (en) | Heavy oil reservoir cone-pressing water plugging method |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| C14 | Grant of patent or utility model | ||
| GR01 | Patent grant |