CN105952425A - Method for improving ordinary heavy oil reservoir recovery ratio by adopting chemical agents to assist CO2 huff and puff - Google Patents
Method for improving ordinary heavy oil reservoir recovery ratio by adopting chemical agents to assist CO2 huff and puff Download PDFInfo
- Publication number
- CN105952425A CN105952425A CN201610541936.4A CN201610541936A CN105952425A CN 105952425 A CN105952425 A CN 105952425A CN 201610541936 A CN201610541936 A CN 201610541936A CN 105952425 A CN105952425 A CN 105952425A
- Authority
- CN
- China
- Prior art keywords
- chemical agent
- volume
- oil
- thinner
- well
- 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
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
- E21B43/164—Injecting CO2 or carbonated water
-
- 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
Abstract
The invention relates to a method for improving the ordinary heavy oil reservoir recovery ratio by adopting chemical agents to assist CO2 huff and puff. The method is characterized by combining the chemical agents with CO2 huff and puff, firstly injecting a viscosity reducer or foaming agent type chemical agent solution slug into an oil well undergoing multiple rounds of CO2 huff and puff, later injecting a high pressure CO2 slug into the well and carrying out soaking after injection is completed. The method has the advantages that during soaking, the viscosity reducer type chemical agents and the ordinary heavy oil form oil-in-water type emulsion, thus substantially reducing the oil-water interfacial tension and reducing the crude oil flow resistance during exploitation; the CO2 gas phase mobility can be controlled and CO2 can be effectively prevented from gas channeling through addition of the foaming agent type chemical agents, so that CO2 diffuses toward the depth of the stratum and the CO2 wave and volume are increased; and due to synergy of the chemical agents and CO2, the oil well can still maintain higher oil production after multiple rounds of huff and puff.
Description
Technical field
The present invention relates to a kind of chemical agent auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, belongs to oil-gas field development
The technical field of engineering.
Background technology
Growing along with global economy, the demand of oil is rapidly increased by the world, through eighties of last century to conventional oil resource
Large-scale exploitation after, viscous crude resource has attracted the attention of common people with its abundant reserves, thus the development technique of heavy crude reservoir
Also receive much concern.Viscous crude is also known as heavy crude or high viscosity oil, by viscosity classification, viscosity under reservoir temperature is higher than
The degassed crude of 100mPa.s is referred to as viscous crude.According to relevant information, the reserves of China's viscous crude occupy the 7th in the world, so far
Have been found that 9 big-and-middle-sized oil basins and large number of heavy crude reservoir block.Countries in the world are in the evolution of petroleum industry
In, it is all that first exploitation is easier to exploitation, lighter crude oil.The country that foreign oil reserves are big, because of its aboundresources and exploit thick
Oil cost is high, risk is big.Along with gradually decreasing of relatively light crude resource, it has to start to exploit the mink cell focus of some more difficult exploitations,
In the most alive boundary stone oil yield, the share of mink cell focus is gradually increased.
At present, the Technology of Heavy Oil Recovery is broadly divided into and cold adopts technology and thermal recovery technology.Heavy crude heat extraction technical matters is complicated, relatively costly；
Heavy oil cold flow production technology mainly includes CO2Handle up, CO2Drive, N2Handle up, chemical flooding etc., wherein CO2Handling up is heavy oil cold flow production
One of topmost mode.
In foreign language literature " Fuel " 03 phase in 2015, " Enhanced oil recovery from tight formations through CO2
Huff ' n ' puff processes " literary composition is mentioned, CO2The purpose of production of heavy oil reservoir of handling up is to pass through CO2Dissolving in viscous crude,
Make viscous crude volumetric expansion, reduce the light components in viscosity of thickened oil and extraction viscous crude, and there is the effect of dissolved gas drive.Its
In substantial amounts of desk research and on-the-spot test show, common heavy oil CO2The raising single well production dose-effect fruit that handles up is notable, CO2Handle up and adopt
Oil can make stripper well strengthening volume increase.But common heavy oil oil well carries out many rounds CO2After handling up, owing to oil gas mobility difference is big,
Cause CO2Has channeling is serious, and swept volume is little, and cycle oil production, oil-gas ratio all can decline along with the increase of round of handling up.As
What improves many rounds CO2The oil recovery of the common heavy oil oil well handled up is a current difficult problem.
Summary of the invention
For existing CO2The deficiency of technology of handling up, the present invention provides a kind of chemical agent auxiliary CO2Handle up raising common heavy oil reservoir
The method of recovery ratio.
Summary of the invention:
The method of the present invention is by chemical agent and CO2Handle up and combine, to carrying out too much round CO2The oil well handled up is initially injected
Thinner or foaming agent class chemical solution slug, backward well in inject high pressure CO2Slug, carries out stewing well after having injected.
During stewing well, thinner class chemical agent forms oil-in-water emulsion with common heavy oil, thus viscosity of crude is greatly reduced, and reduces
Crude oil flow resistance during exploitation.And the addition of foaming agent class chemical agent can improve displacement efficiency, control CO2Gas phase mobility, has
Prevent CO to effect2There is has channeling, increase CO2Gas swept volume.Chemical agent and CO2Synergism many rounds are handled up
After, oil well still is able to keep higher oil production.
Explanation of nouns:
Common heavy oil: under reservoir condition, viscosity of crude is the viscous crude of 50～1000mPa.s, this type of flooding for heavy oil development effectiveness is poor,
Currently mainly with CO2Handle up, steam soak and steam drive etc., and development scheme is main.
Chemical agent: be divided into thinner class and foaming agent class.Wherein, thinner class chemical agent can be effectively reduced oil-water interfaces and opens
Power, forms oil-in-water emulsion, thus viscosity of crude is greatly reduced；Foaming agent class chemical agent can make CO2Gas involves body
Long-pending increase, effectively controls CO2Gas phase mobility, forming part foam oil.Due to CO2Synergism with chemical agent so that oil
Well, after high round is handled up, still is able to keep higher oil production.
Technical scheme is as follows:
A kind of chemical agent auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, comprises the following steps that
(1) chemical solution slug injects: chemical agent is configured to chemical agent aqueous solution, pit shaft injects stratum, chemical agent water
The mass concentration of solution is 0.1～2.0%, and the volume injecting chemical agent aqueous solution is 8m3～20m3；
(2)CO2Slug injects: by CO2Slug injects in stratum by pit shaft, CO under the reservoir condition of injection2Volume with
The volume ratio of the chemical agent aqueous solution injected is 0.5:1～5:1；
(3) stewing well diffusion: by CO2After injecting oil reservoir, closing well carries out stewing well, stewing well time 7d～14d, during stewing well, changes
Learn agent and viscosity of crude, CO are greatly reduced2Extract with crude oil, volumetric expansion, the effect such as dissolving viscosity reduction；
(4) opening well and making production: stewing well terminates rear opening well and making production, during stratum filtration, CO2Mix with chemical agent, CO2Gas
Body displacement crude oil and emulsion, from formation flow to pit shaft, are finally adopted to ground；
Currently preferred, treat the chemical agent auxiliary CO of a round2Handle up after end, repeat step (1)～step (4),
Carry out 2-5 round to handle up, improve many rounds CO2The oil production of oil well after handling up.
Currently preferred, described chemical agent is thinner and/or foaming agent.
Currently preferred, when described chemical agent is water solublity thinner, the mass concentration of step (1) thinner aqueous solution
Being 0.2～1.0%, the volume injecting thinner aqueous solution is 10m3～20m3；CO under the reservoir condition that step (2) is injected2's
Volume is 1:1～5:1 with the ratio of the volume of the thinner solution of injection；During the stewing well of step (3), thinner and common heavy oil
Form oil-in-water emulsion, viscosity of crude, CO are greatly reduced2Extract with crude oil, volumetric expansion, dissolving viscosity reduction etc. are made
With；The stewing well of step (4) terminates rear opening well and making production, during stratum filtration, CO2Mix with water-oil emulsion, CO2Gas
Displacement crude oil and emulsion, from formation flow to pit shaft, are finally adopted to ground.
It is further preferred that the mass concentration of thinner aqueous solution is 1.0%, the volume injecting thinner aqueous solution is 12m3, note
CO under the reservoir condition entered2The ratio of volume and the volume of the thinner solution of injection be 1:1.
Currently preferred, when described chemical agent is foaming agent, the mass concentration of step (1) foaming agent is 0.2～0.5%,
The volume injecting foaming agent aqueous solution is 15m3～20m3；CO under the reservoir condition that step (2) is injected2The rising of volume and injection
The ratio of the volume of infusion solution is 2:1～5:1；During the stewing well of step (3), foaming agent solution can improve displacement efficiency, increases
Add CO2Swept volume, CO2Can extract with crude oil, volumetric expansion, the effect such as dissolving viscosity reduction；Step (4) stewing well knot
Opening well and making production after bundle, during stratum filtration, CO2Mix with foaming agent solution, can effectively control CO2Mobility, CO2Gas
Body displacement crude oil and mixed liquor, from formation flow to pit shaft, are finally adopted to ground.
It is further preferred that the mass concentration of foaming agent is 0.5%, the volume injecting foaming agent aqueous solution is 15m3；The oil injected
CO under the conditions of Tibetan2The ratio of volume and the volume of the foaming agent solution of injection be 2:1.
Currently preferred, described water solublity thinner is the thinner that viscosity of crude can be made to reduce 90-98%, it is preferred that
Water solublity thinner is alkyl sulfonates, alkyl benzene sulfonate, polyoxyethylated alkyl alcohol class thinner.
Alkyl sulfonates, alkyl benzene sulfonate, polyoxyethylated alkyl alcohol class thinner is prior art, conventional commercial product
Product.
Currently preferred, described foaming agent is two-(2-ethylhexyl)-sulfonic acid sodium succinate (AOT) and/or fatty acid polyoxy
Ethylene polyethenoxy ether (C12E9P3)。
It is an advantage of the current invention that:
Chemical agent the most of the present invention auxiliary CO2The process of raising common heavy oil reservoir recovery ratio of handling up can solve effectively
Certainly high round CO2The problem that huff and puff oil recovery amount declines rapidly.The chemical agent injected can make CO2Spread to depths, stratum, improve
CO2Gas swept volume so that distance well head in-place oil remotely is plucked out of, thus improves high round CO2Handle up
Oil production.
2. the present invention assists CO at chemical agent2Handling up during stewing well, the thinner class chemical agent of use can be with common heavy oil shape
Become oil-in-water emulsion, interfacial tension is greatly reduced, reduces viscous crude flow resistance；During opening well and making production, use
Foaming agent class chemical agent can control CO2Gas phase mobility, is effectively prevented CO2There is has channeling, thus improve high round CO2
The oil production handled up.
Accompanying drawing explanation
Fig. 1 is that chemical agent assists CO2The schematic diagram of the process improving common heavy oil reservoir recovery ratio of handling up；
In figure, 1, high pressure CO2Storage tank；2, ground supercharging injection device；3, well is injected；4, chemical agent aqueous solution storage tank；5、
Straight well；6, common heavy oil reservoir.
Fig. 2 is that chemical agent assists CO2Handle up and CO2Handle up respectively handle up round recovery percent of reserves contrast block diagram.
Detailed description of the invention
Below in conjunction with embodiment and Figure of description, the present invention is described further, but is not limited to this.
Embodiment 1
A kind of chemical agent auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, flow process is as it is shown in figure 1, pass through pressure
Pipeline is by high pressure CO2Storage tank 1 exit is connected with ground injection device 2, connects ground injection device 2 by pipeline and injects
Well 3, foaming agent aqueous solution storage tank 4 is connected with ground injection device 2 by pipeline, connects ground injection device 2 by pipeline
With injection well 3.
Specifically include step as follows:
(1) foaming agent solution slug injection process: two-(2-ethylhexyl)-sulfonic acid sodium succinate foaming agent is configured to foaming agent water
Solution, is injected stratum by pit shaft, and the mass concentration of foaming agent aqueous solution is 0.5%, and the volume injecting foaming agent aqueous solution is 15m3；
(2) high pressure CO2Slug injection process: by CO2Slug passes through ground supercharging equipment supercharging, pit shaft inject reservoir, note
CO under the reservoir condition entered2The volume ratio of chemical agent aqueous solution of volume and injection be 2:1；
(3) stewing well diffusion: by CO2After injecting oil reservoir, closing well carries out stewing well, stewing well time 7d, pressure during the stewing well of record
Change.CO during stewing well2Extract with crude oil, volumetric expansion, the effect such as dissolving viscosity reduction；
After (4) one weeks, opening well and making production.The addition of foaming agent solution, can increase CO2Gas swept volume, controls CO2Stream
Degree, is effectively prevented CO2There is has channeling.CO2Gas displacement crude oil etc. flow to pit shaft from oil reservoir, finally adopts to ground；
(5) the foaming agent auxiliary CO of a round is treated2Handle up after end, repeat step (1)～step (4) 3 times, it is achieved
The foaming agent auxiliary CO of many rounds2Handle up, improve many rounds CO2Huff and puff oil recovery amount.
Embodiment 2
A kind of chemical agent auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, specifically includes step as follows:
(1) thinner solution slug injection process: alkyl sulfonates thinner is configured to thinner aqueous solution, pit shaft notes
Entering stratum, the mass concentration of thinner aqueous solution is 1.0%, and the volume injecting thinner aqueous solution is 12m3；
(2) high pressure CO2Slug injection process: by CO2Slug passes through ground supercharging equipment supercharging, pit shaft inject reservoir, note
CO under the reservoir condition entered2The volume ratio of chemical agent aqueous solution of volume and injection be 1:1；
(3) stewing well diffusion: by CO2After injecting oil reservoir, closing well carries out stewing well, stewing well time 10d, presses during the stewing well of record
The change of power.During stewing well, thinner forms oil-in-water emulsion with common heavy oil, and viscosity of crude, CO are greatly reduced2
Extract with crude oil, volumetric expansion, the effect such as dissolving viscosity reduction；
(4) stewing well terminates rear opening well and making production, during stratum filtration, CO2Mix with water-oil emulsion, CO2Gas displacement
Crude oil and emulsion, from formation flow to pit shaft, are finally adopted to ground.
(5) the thinner auxiliary CO of a round is treated2Handle up after end, repeat step (1)～step (4) 4 times, it is achieved
The thinner auxiliary CO of many rounds2Handle up, improve many rounds CO2Huff and puff oil recovery amount.
Embodiment 3
Simulation chemical agent auxiliary CO2Handle up and exploit the experimental provision of common heavy oil reservoir mainly by the double plunger metering of displacement liquid
The compositions such as the control of pump, the double plunger dosing pump of displacing gases, pressure transmitter, balance, fill out sand tube, temperature and pressure and record system,
Experiment is carried out, to simulate reservoir media under stationary temperature, pressure.
Concretely comprise the following steps:
(1) utilize fill out sand tube to fill and present the rock core of certain permeability, weigh dry weight, evacuation, saturation water, weigh weight in wet base, calculate
Porosity, measures rock core water phase permeability；
(2) rock core is adjusted to formation temperature 60 DEG C and strata pressure；
(3) with the speed saturated oils of 0.5ml/min, until port of export product fluid is the most aqueous, closes the rock core port of export and stablize
A period of time；
(4) CO is injected from injection end with the speed of 0.5ml/min2, work as CO2When amount injection reaches 24ml, stop gas injection,
Close injection end stewing well 12h；
(5) open injection end valve, make oil gas spue under the pressure drop gradient of 1MPa/min, record oil production；
(6) repeat step (4)～step (5), carry out the CO of next one2Handle up experiment；
(7) by foaming agent aliphatic acid polyethenoxy polyethenoxy ether (C12E9P3) be dissolved in formation water and be configured to mass concentration and be
The solution of 0.5%, pours in intermediate receptacle；
(8) foaming agent solution slug is injected, when aliphatic acid polyethenoxy polyethenoxy ether from injection end with the speed of 1ml/min
(C12E9P3) foaming agent solution injection rate is when reaching 12ml, stop injecting, be then injected into the high pressure CO of 24ml2Slug, closes
Close injection end stewing well certain time；
(9) open injection end valve after stewing well 12h, make oil, gas, foaming agent solution tell under the pressure drop gradient of 1MPa/min
Go out, record oil production；
The foaming agent auxiliary CO of (10) rounds2Handle up after end, repeat step (8)～step (9) three times, it is achieved 4
The foaming agent auxiliary CO of individual round2Handle up.
(11) contrast CO2Handle up displacement crude oil, inject the high pressure CO of 24ml2, it is not injected into foaming agent solution, closes injection end
Valve carries out 12h and boils in a covered pot over a slow fire opening well and making production after well, the cycle oil production of record opening well and making production, carries out the CO of 6 rounds2Handle up.
Experimental result is as in figure 2 it is shown, contrast chemical agent assists CO2Handle up and CO2Handle up, chemical agent auxiliary CO2Handle up and have
Higher recovery ratio, after 6 rounds of handling up, overall recovery factor has reached 41.96%, achieves preferable exploitation effect.
Claims (9)
1. a chemical agent auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, comprises the following steps that
(1) chemical solution slug injects: chemical agent being configured to chemical agent aqueous solution, pit shaft injects stratum, the mass concentration of chemical agent aqueous solution is 0.1～2.0%, and the volume injecting chemical agent aqueous solution is 8m3～20m3；
(2)CO2Slug injects: by CO2Slug injects in stratum by pit shaft, CO under the reservoir condition of injection2The volume ratio of chemical agent aqueous solution of volume and injection be 0.5:1～5:1；
(3) stewing well diffusion: by CO2After injecting oil reservoir, closing well carries out stewing well, stewing well time 7d～14d, and during stewing well, chemical agent is greatly reduced viscosity of crude, CO2Extract with crude oil, volumetric expansion, the effect such as dissolving viscosity reduction；
(4) opening well and making production: stewing well terminates rear opening well and making production, during stratum filtration, CO2Mix with chemical agent, CO2Gas displacement crude oil and emulsion, from formation flow to pit shaft, are finally adopted to ground.
Chemical agent the most according to claim 1 auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, it is characterised in that treat the chemical agent auxiliary CO of a round2Handle up after end, repeat step (1)～step (4), carry out 2-5 round and handle up, improve many rounds CO2The oil production of oil well after handling up.
Chemical agent the most according to claim 1 auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, it is characterised in that described chemical agent is thinner and/or foaming agent.
Chemical agent the most according to claim 3 auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, it is characterised in that when described chemical agent is water solublity thinner, the mass concentration of step (1) thinner aqueous solution is 0.2～1.0%, the volume injecting thinner aqueous solution is 10m3～20m3；CO under the reservoir condition that step (2) is injected2The ratio of volume and the volume of the thinner solution of injection be 1:1～5:1；During the stewing well of step (3), thinner forms oil-in-water emulsion with common heavy oil, and viscosity of crude, CO are greatly reduced2Extract with crude oil, volumetric expansion, the effect such as dissolving viscosity reduction；The stewing well of step (4) terminates rear opening well and making production, during stratum filtration, CO2Mix with water-oil emulsion, CO2Gas displacement crude oil and emulsion, from formation flow to pit shaft, are finally adopted to ground.
Chemical agent the most according to claim 4 auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, it is characterised in that the mass concentration of thinner aqueous solution is 1.0%, the volume injecting thinner aqueous solution is 12m3, CO under the reservoir condition of injection2The ratio of volume and the volume of the thinner solution of injection be 1:1.
Chemical agent the most according to claim 3 auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, it is characterised in that when described chemical agent is foaming agent, the mass concentration of step (1) foaming agent is 0.2～0.5%, the volume injecting foaming agent aqueous solution is 15m3～20m3；CO under the reservoir condition that step (2) is injected2The ratio of volume and the volume of the foaming agent solution of injection be 2:1～5:1；During the stewing well of step (3), foaming agent solution can improve displacement efficiency, increases CO2Swept volume, CO2Can extract with crude oil, volumetric expansion, the effect such as dissolving viscosity reduction；The stewing well of step (4) terminates rear opening well and making production, during stratum filtration, CO2Mix with foaming agent solution, can effectively control CO2Mobility, CO2Gas displacement crude oil and mixed liquor, from formation flow to pit shaft, are finally adopted to ground.
Chemical agent the most according to claim 6 auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, it is characterised in that the mass concentration of foaming agent is 0.5%, the volume injecting foaming agent aqueous solution is 15m3；CO under the reservoir condition injected2The ratio of volume and the volume of the foaming agent solution of injection be 2:1.
Chemical agent the most according to claim 3 auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, it is characterised in that described water solublity thinner is the thinner that viscosity of crude can be made to reduce 90-98%, preferably, water solublity thinner is alkyl sulfonates, alkyl benzene sulfonate, polyoxyethylated alkyl alcohol class thinner.
Chemical agent the most according to claim 3 auxiliary CO2The method of raising common heavy oil reservoir recovery ratio of handling up, it is characterised in that described foaming agent is two-(2-ethylhexyl)-sulfonic acid sodium succinate (AOT) and/or aliphatic acid polyethenoxy polyethenoxy ether (C12E9P3)。
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610541936.4A CN105952425B (en) | 2016-07-11 | 2016-07-11 | A kind of chemical agent auxiliary CO2It handles up the method for improving common heavy oil reservoir recovery ratio |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610541936.4A CN105952425B (en) | 2016-07-11 | 2016-07-11 | A kind of chemical agent auxiliary CO2It handles up the method for improving common heavy oil reservoir recovery ratio |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN105952425A true CN105952425A (en) | 2016-09-21 |
| CN105952425B CN105952425B (en) | 2019-05-28 |
Family
ID=56899808
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201610541936.4A Active CN105952425B (en) | 2016-07-11 | 2016-07-11 | A kind of chemical agent auxiliary CO2It handles up the method for improving common heavy oil reservoir recovery ratio |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN105952425B (en) |
Cited By (25)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106499347A (en) * | 2016-10-28 | 2017-03-15 | 中国石油天然气股份有限公司 | A kind of oil recovery flow string and methods for using them |
| CN107288594A (en) * | 2017-09-04 | 2017-10-24 | 中国石油化工股份有限公司华东油气分公司泰州采油厂 | A kind of pressure injection system and method for improving CO_2 stimulation effect |
| CN107558974A (en) * | 2017-09-04 | 2018-01-09 | 中国石油化工股份有限公司华东油气分公司泰州采油厂 | A kind of horizontal wells in heavy oil reservoir precipitation yield-increasing technology |
| CN107869336A (en) * | 2016-09-23 | 2018-04-03 | 中国石油化工股份有限公司 | Super-viscous oil chemistry auxiliary thermal recovery improves recovery ratio method |
| CN108661614A (en) * | 2017-03-30 | 2018-10-16 | 中国石油天然气股份有限公司 | Fine and close oil reservoir supercritical CO2Huff and puff oil recovery method |
| CN108868721A (en) * | 2018-08-01 | 2018-11-23 | 中国石油天然气股份有限公司 | A method of associated gas after desulfurization is driven using steam carry out viscous crude handle up well viscosity reduction |
| CN108979603A (en) * | 2018-08-01 | 2018-12-11 | 中国石油天然气股份有限公司 | The method for driving associated gas realization oil-water well volume increase after desulfurization using steam |
| CN109082269A (en) * | 2018-08-01 | 2018-12-25 | 中国石油天然气股份有限公司 | With associated gas after steam drive desulfurization to the method for the heavy oil block gas drive of waterflooding development |
| CN109386263A (en) * | 2017-08-10 | 2019-02-26 | 中国石油天然气股份有限公司 | A method of improving deep-well oil recovery |
| CN109388771A (en) * | 2017-08-03 | 2019-02-26 | 中国石油化工股份有限公司 | A kind of deep-layer heavy crude foam oil viscosity reduction is handled up the calculation method of well manufacturing parameter |
| CN109812249A (en) * | 2017-11-20 | 2019-05-28 | 中国石油化工股份有限公司 | Oil reservoir oil displacement method |
| CN110905460A (en) * | 2019-12-02 | 2020-03-24 | 中国石油化工股份有限公司 | Viscosity-reducing foaming exploitation method for common heavy oil reservoir |
| CN111022013A (en) * | 2019-12-03 | 2020-04-17 | 中国石油化工股份有限公司 | Steam huff and puff oil production method for heterogeneous heavy oil reservoir |
| CN112780238A (en) * | 2019-11-11 | 2021-05-11 | 中国石油天然气股份有限公司 | Method for exploiting limestone light oil reservoir |
| CN113153209A (en) * | 2020-01-07 | 2021-07-23 | 中国石油天然气股份有限公司 | Multi-medium composite huff and puff development method for heavy oil reservoir |
| CN113882841A (en) * | 2021-10-20 | 2022-01-04 | 中国石油化工股份有限公司 | Nano-system composite CO2Method for improving oil well productivity through huff and puff |
| CN113880716A (en) * | 2020-07-01 | 2022-01-04 | 中国石油化工股份有限公司 | Phloroglucinol polyether carboxylic ester, composition and preparation method thereof, and deep-layer low-permeability heavy oil CO2Viscosity-reducing synergistic method |
| CN114075955A (en) * | 2020-08-17 | 2022-02-22 | 中国石油天然气股份有限公司 | Gaseous CO2Steam huff-puff channeling-preventing and injection-increasing assisting method |
| CN114233255A (en) * | 2021-12-21 | 2022-03-25 | 浙江工业大学 | Method for reducing viscosity of thickened oil by using microbial conversion solution |
| CN114622881A (en) * | 2020-12-14 | 2022-06-14 | 中国石油化工股份有限公司 | Low-permeability heavy oil reservoir viscosity-reduction pressure-reduction driving exploitation method |
| CN115124989A (en) * | 2021-03-29 | 2022-09-30 | 中国石油化工股份有限公司 | Viscosity-reducing cold recovery method for thickened oil and application thereof |
| CN115126455A (en) * | 2021-03-24 | 2022-09-30 | 中国石油化工股份有限公司 | Chemical composite cold recovery method for strong water-sensitive heavy oil reservoir and application thereof |
| CN115288644A (en) * | 2022-08-22 | 2022-11-04 | 大庆信辰油田技术服务有限公司 | Method for improving crude oil recovery ratio by combining hypotonic reservoir with carbon dioxide huff and puff |
| CN116066045A (en) * | 2023-04-04 | 2023-05-05 | 中国石油大学(华东) | Thermal recovery method for improving recovery ratio of low-permeability heavy oil reservoir |
| US11668171B2 (en) | 2021-08-31 | 2023-06-06 | Saudi Arabian Oil Company | Methodology to increase oil production rates in gravity drainage CO2 gas injection processes |
Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| RU2021495C1 (en) * | 1991-05-12 | 1994-10-15 | Всесоюзный нефтегазовый научно-исследовательский институт | Method for development of oil field |
| CN101255788A (en) * | 2008-04-15 | 2008-09-03 | 中国石化集团胜利石油管理局石油开发中心 | Thermochemistry auxiliary reinforced steam flooding method |
| CN104265254A (en) * | 2014-09-06 | 2015-01-07 | 中国石油化工股份有限公司 | Oil production technological method for multi-stage plug injection of oil-soluble viscosity reducer and liquid CO2 in deep super-heavy oil |
| CN104847320A (en) * | 2014-02-13 | 2015-08-19 | 中国石油化工股份有限公司 | Ultra-deep-seated and low-permeable thickened oil identified viscosity reduction method |
| CN104847317A (en) * | 2014-02-13 | 2015-08-19 | 中国石油化工股份有限公司 | Method for raising recovery efficiency of super-deep low permeability heavy oil reservoir |
| CN105134146A (en) * | 2015-07-07 | 2015-12-09 | 西北大学 | Method for oil displacement using carbon dioxide and foam |
-
2016
- 2016-07-11 CN CN201610541936.4A patent/CN105952425B/en active Active
Patent Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| RU2021495C1 (en) * | 1991-05-12 | 1994-10-15 | Всесоюзный нефтегазовый научно-исследовательский институт | Method for development of oil field |
| CN101255788A (en) * | 2008-04-15 | 2008-09-03 | 中国石化集团胜利石油管理局石油开发中心 | Thermochemistry auxiliary reinforced steam flooding method |
| CN104847320A (en) * | 2014-02-13 | 2015-08-19 | 中国石油化工股份有限公司 | Ultra-deep-seated and low-permeable thickened oil identified viscosity reduction method |
| CN104847317A (en) * | 2014-02-13 | 2015-08-19 | 中国石油化工股份有限公司 | Method for raising recovery efficiency of super-deep low permeability heavy oil reservoir |
| CN104265254A (en) * | 2014-09-06 | 2015-01-07 | 中国石油化工股份有限公司 | Oil production technological method for multi-stage plug injection of oil-soluble viscosity reducer and liquid CO2 in deep super-heavy oil |
| CN105134146A (en) * | 2015-07-07 | 2015-12-09 | 西北大学 | Method for oil displacement using carbon dioxide and foam |
Cited By (37)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107869336A (en) * | 2016-09-23 | 2018-04-03 | 中国石油化工股份有限公司 | Super-viscous oil chemistry auxiliary thermal recovery improves recovery ratio method |
| CN106499347A (en) * | 2016-10-28 | 2017-03-15 | 中国石油天然气股份有限公司 | A kind of oil recovery flow string and methods for using them |
| CN106499347B (en) * | 2016-10-28 | 2018-11-16 | 中国石油天然气股份有限公司 | A kind of application method of oil recovery flow string |
| CN108661614A (en) * | 2017-03-30 | 2018-10-16 | 中国石油天然气股份有限公司 | Fine and close oil reservoir supercritical CO2Huff and puff oil recovery method |
| CN109388771B (en) * | 2017-08-03 | 2023-05-02 | 中国石油化工股份有限公司 | Calculation method for production parameters of deep thickened oil foam oil viscosity-reducing huff-puff well |
| CN109388771A (en) * | 2017-08-03 | 2019-02-26 | 中国石油化工股份有限公司 | A kind of deep-layer heavy crude foam oil viscosity reduction is handled up the calculation method of well manufacturing parameter |
| CN109386263A (en) * | 2017-08-10 | 2019-02-26 | 中国石油天然气股份有限公司 | A method of improving deep-well oil recovery |
| CN107288594B (en) * | 2017-09-04 | 2019-08-02 | 中国石油化工股份有限公司华东油气分公司泰州采油厂 | A kind of pressure injection system and method improving CO_2 stimulation effect |
| CN107558974A (en) * | 2017-09-04 | 2018-01-09 | 中国石油化工股份有限公司华东油气分公司泰州采油厂 | A kind of horizontal wells in heavy oil reservoir precipitation yield-increasing technology |
| CN107288594A (en) * | 2017-09-04 | 2017-10-24 | 中国石油化工股份有限公司华东油气分公司泰州采油厂 | A kind of pressure injection system and method for improving CO_2 stimulation effect |
| CN109812249A (en) * | 2017-11-20 | 2019-05-28 | 中国石油化工股份有限公司 | Oil reservoir oil displacement method |
| CN109812249B (en) * | 2017-11-20 | 2023-08-08 | 中国石油化工股份有限公司 | Oil reservoir oil displacement method |
| CN109082269A (en) * | 2018-08-01 | 2018-12-25 | 中国石油天然气股份有限公司 | With associated gas after steam drive desulfurization to the method for the heavy oil block gas drive of waterflooding development |
| CN108979603A (en) * | 2018-08-01 | 2018-12-11 | 中国石油天然气股份有限公司 | The method for driving associated gas realization oil-water well volume increase after desulfurization using steam |
| CN108868721A (en) * | 2018-08-01 | 2018-11-23 | 中国石油天然气股份有限公司 | A method of associated gas after desulfurization is driven using steam carry out viscous crude handle up well viscosity reduction |
| CN109082269B (en) * | 2018-08-01 | 2021-03-30 | 中国石油天然气股份有限公司 | Thickened oil block gas flooding method for water flooding development by associated gas after steam flooding desulfurization |
| CN112780238B (en) * | 2019-11-11 | 2022-12-02 | 中国石油天然气股份有限公司 | Method for exploiting limestone light oil reservoir |
| CN112780238A (en) * | 2019-11-11 | 2021-05-11 | 中国石油天然气股份有限公司 | Method for exploiting limestone light oil reservoir |
| CN110905460B (en) * | 2019-12-02 | 2021-08-20 | 中国石油化工股份有限公司 | Viscosity-reducing foaming exploitation method for common heavy oil reservoir |
| CN110905460A (en) * | 2019-12-02 | 2020-03-24 | 中国石油化工股份有限公司 | Viscosity-reducing foaming exploitation method for common heavy oil reservoir |
| CN111022013A (en) * | 2019-12-03 | 2020-04-17 | 中国石油化工股份有限公司 | Steam huff and puff oil production method for heterogeneous heavy oil reservoir |
| CN113153209A (en) * | 2020-01-07 | 2021-07-23 | 中国石油天然气股份有限公司 | Multi-medium composite huff and puff development method for heavy oil reservoir |
| CN113880716B (en) * | 2020-07-01 | 2024-01-26 | 中国石油化工股份有限公司 | Phloroglucinol polyether carboxylate and composition, preparation method and deep hypotonic thickened oil CO thereof 2 Viscosity-reducing and efficiency-increasing method |
| CN113880716A (en) * | 2020-07-01 | 2022-01-04 | 中国石油化工股份有限公司 | Phloroglucinol polyether carboxylic ester, composition and preparation method thereof, and deep-layer low-permeability heavy oil CO2Viscosity-reducing synergistic method |
| CN114075955A (en) * | 2020-08-17 | 2022-02-22 | 中国石油天然气股份有限公司 | Gaseous CO2Steam huff-puff channeling-preventing and injection-increasing assisting method |
| CN114622881A (en) * | 2020-12-14 | 2022-06-14 | 中国石油化工股份有限公司 | Low-permeability heavy oil reservoir viscosity-reduction pressure-reduction driving exploitation method |
| CN115126455A (en) * | 2021-03-24 | 2022-09-30 | 中国石油化工股份有限公司 | Chemical composite cold recovery method for strong water-sensitive heavy oil reservoir and application thereof |
| CN115124989A (en) * | 2021-03-29 | 2022-09-30 | 中国石油化工股份有限公司 | Viscosity-reducing cold recovery method for thickened oil and application thereof |
| CN115124989B (en) * | 2021-03-29 | 2023-06-13 | 中国石油化工股份有限公司 | Thickened oil viscosity-reducing cold recovery method and application thereof |
| US11668171B2 (en) | 2021-08-31 | 2023-06-06 | Saudi Arabian Oil Company | Methodology to increase oil production rates in gravity drainage CO2 gas injection processes |
| CN113882841A (en) * | 2021-10-20 | 2022-01-04 | 中国石油化工股份有限公司 | Nano-system composite CO2Method for improving oil well productivity through huff and puff |
| CN114233255A (en) * | 2021-12-21 | 2022-03-25 | 浙江工业大学 | Method for reducing viscosity of thickened oil by using microbial conversion solution |
| CN114233255B (en) * | 2021-12-21 | 2024-03-12 | 浙江工业大学 | Method for reducing viscosity of thick oil by utilizing microbial conversion liquid |
| CN115288644B (en) * | 2022-08-22 | 2023-03-10 | 大庆信辰油田技术服务有限公司 | Method for improving crude oil recovery ratio by combining hypotonic reservoir with carbon dioxide huff and puff |
| CN115288644A (en) * | 2022-08-22 | 2022-11-04 | 大庆信辰油田技术服务有限公司 | Method for improving crude oil recovery ratio by combining hypotonic reservoir with carbon dioxide huff and puff |
| CN116066045A (en) * | 2023-04-04 | 2023-05-05 | 中国石油大学(华东) | Thermal recovery method for improving recovery ratio of low-permeability heavy oil reservoir |
| CN116066045B (en) * | 2023-04-04 | 2023-06-02 | 中国石油大学(华东) | Thermal recovery method for improving recovery ratio of low-permeability heavy oil reservoir |
Also Published As
| Publication number | Publication date |
|---|---|
| CN105952425B (en) | 2019-05-28 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN105952425A (en) | Method for improving ordinary heavy oil reservoir recovery ratio by adopting chemical agents to assist CO2 huff and puff | |
| CN106089166A (en) | A kind of fine and close oil reservoir CO2foam handle up improve recovery ratio method | |
| CN101255788B (en) | Thermochemistry auxiliary reinforced steam flooding method | |
| CN101839123B (en) | Exploitation method for wax precipitation oil reservoir | |
| CN103790561B (en) | The more rounds of thin heavy oil are handled up later stage recovery method | |
| CN110318721B (en) | Method for improving recovery ratio by foam flooding auxiliary nitrogen huff and puff of fault block oil reservoir | |
| CN101016835B (en) | Thermal production well filling vapor and nitrogen foam profile control technique | |
| CN105114048A (en) | Horizontal well staged fracturing oil production method through injection and production in same well | |
| CN103206199B (en) | Device and method for exploiting natural gas hydrates by means of thermal fluid fracturing | |
| CN109209306B (en) | Horizontal well CO injection for ultra-low permeability tight oil reservoir2Asynchronous throughput energy supplementing method | |
| CN102635342B (en) | Thermo-chemical oil extraction method of offshore thickened oil | |
| CN104314541B (en) | A kind of multielement hot fluid is handled up the method for production of heavy oil reservoir | |
| CN104314539A (en) | Artificial foaming-oil huff and puff oil production method for heavy oil reservoir | |
| CN105201468B (en) | A kind of method of UNICOM between auxiliary water horizontal well | |
| CN104265254A (en) | Oil production technological method for multi-stage plug injection of oil-soluble viscosity reducer and liquid CO2 in deep super-heavy oil | |
| CN106930740A (en) | A kind of method for injecting saturation hot brine stimulation for natural gas hydrate dissociation | |
| CN102080522A (en) | Oil extraction method for oil deposit of shallow-layer super heavy oil | |
| CN104747148A (en) | Thin and shallow layer super heavy oil horizontal well, viscosity reducer, nitrogen and steam assisted huff and puff method | |
| CN109113700A (en) | A kind of method of heavy crude reservoir old area multimedium steam oil production | |
| CN111022013A (en) | Steam huff and puff oil production method for heterogeneous heavy oil reservoir | |
| CN102051161B (en) | Thick oil huff and puff deep channel blocking system and injection method thereof | |
| CN104847320A (en) | Ultra-deep-seated and low-permeable thickened oil identified viscosity reduction method | |
| CN103289665B (en) | Displacement composition, containing its multielement hot fluid displacement composition and displacement method | |
| CN114370260A (en) | Heat composite huff-puff synergy system for offshore high-water-content heavy oil cold production well and operation method thereof | |
| Sun et al. | Insights into enhanced oil recovery by thermochemical fluid flooding for ultra-heavy reservoirs: An experimental study |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |