CN105089590A - Method for improving yield of common heavy oil reservoir after water flooding - Google Patents
Method for improving yield of common heavy oil reservoir after water flooding Download PDFInfo
- Publication number
- CN105089590A CN105089590A CN201410194080.9A CN201410194080A CN105089590A CN 105089590 A CN105089590 A CN 105089590A CN 201410194080 A CN201410194080 A CN 201410194080A CN 105089590 A CN105089590 A CN 105089590A
- Authority
- CN
- China
- Prior art keywords
- oil reservoir
- oil
- water
- heavy oil
- common heavy
- 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.)
- Pending
Links
Abstract
The invention discloses a method for improving the yield of a common heavy oil reservoir after water flooding. According to the method, in the hot water flooding process, oil-soluble viscosity reducers and flue gas section slugs are periodically injected into a steam injection well. The method comprises the following steps of a, injecting a hot water and smoke gas mixture accounting for 0.15 to 0.2 time of the volume of formation pores; b, injecting the oil-soluble viscosity reducers into the water injection well for 5 to 10d; c, injecting the hot water and flue gas mixture for 60 to 80d; and d, repeating the step b and the step c. The method has the advantages that the high-temperature-resistant oil-soluble viscosity reducers are adopted; the crude oil viscosity can be obviously reduced; the crude oil flowability is improved; the crude oil yield is improved; meanwhile, flue gas generated through boiler combustion can be directly injected to an underground position; the heat efficiency can be improved; and the environment pollution can be reduced.
Description
Technical field
The present invention relates to oil extraction in oil field technical field, particularly a kind of flue gas and thinner auxiliary heat water drive of utilizing is to improve the method for common heavy oil reservoir recovery ratio after water drive.
Background technology
Viscous crude occupies larger ratio in World's Oil and Gas Resources.According to statistics, the reserves of world's viscous crude, super-viscous oil and natural asphalt are about 1000 × 108t.China's viscous crude resource distribution is extensive, has found more than 70 viscous crude field in 12 basins.The exploitation of viscous crude has very large potentiality, and along with the minimizing of light oil mine reserves, and the proportion shared by 21 century heavy crude producing will constantly increase.
Domestic have abundant common heavy oil resource (formation condition viscosity >50mPas), only Shengli Oil Field oil in place 10.5 × 108t.Shengli Oil Field waterflooding development common heavy oil reservoir, by the impact of viscosity of crude, development effectiveness difference is very large.Underground viscosity of crude is less than the general recovery ratio of 100mPas higher than 20%, and rate of oil production is greater than 1%; Underground viscosity of crude is greater than 100mPas recovery ratio generally lower than 20%, and rate of oil production is less than 1%.Containing a large amount of residual recoverable reserves in oil reservoir, therefore improve the recovery ratio of such oil reservoir in the urgent need to conversion development scheme.
Steam soak is that the tradition generally used at present improves thick oil recovery ratio technology, but steam soak heating radius is limited, generally only 30-40m, and oil recovery factor is low, generally only has 10%-15%, the most about about 20%.Steam flooding is steam soak later stage the most effective substituted technique, but steam driving exploitation air consumption is large, and running cost is high, and geology reservoir is strict.Triumph water drive viscous crude belongs to steam flooding Margin reservoir, and oil reservoir buries 1200-1600m, is difficult to ensure shaft bottom high mass dryness fraction steam injection, the simultaneously edge-bottom water that comparatively enlivens of ubiquity, energy supplement is sufficient, is difficult to step-down, and strata pressure is high is unfavorable for that steam zone spreads, vapour drives weak effect.So in the oil reservoir taking steam soak to develop, some are not suitable for the oil reservoir of steam drive development, recommend to adopt hot water flooding.
In viscous crude, the content of solid hydrocarbons, asphalitine and colloid and composition are the principal elements determining its mobility, and viscous crude studies on asphaltene and gum level are high especially, and their complex structure, and molecular weight is large.By adding oil soluble heavy crude thinner, reducing the hydrogen bond action between resin and asphalt, making its structure become loose, thus reach and reduce viscosity of thickened oil, improve viscous crude mobility, solve the exploitation of viscous crude and collect the object of defeated problem.
The present invention is by compound viscous crude chemical viscosity reduction, steam viscosity reduction and flue gas function of heat insulation three kinds of mechanism, and what can give full play to two kinds of technology adds effect effect, the recovery ratio of common heavy oil reservoir after effective raising water drive.
Summary of the invention
The object of this invention is to provide one drives in process flue gas side het water, periodically injects oil-soluble viscosity reducer slug to water injection well, the flooding method of common heavy oil reservoir recovery ratio after raising water drive.
In order to reach above-mentioned purpose, the present invention realizes by following technical measures:
Improve a method for common heavy oil reservoir recovery ratio after water drive, carry out as follows:
A. the hot water of 0.15 ~ 0.2 times of formation pore volume and the mixture of flue gas is injected;
B. oil-soluble viscosity reducer solution is injected water injection well 5 ~ 10d;
C. hot-water flooding and flue gas mixture 60 ~ 80d;
D. step b, c is repeated.
Object of the present invention also realizes by following technical measures:
Described hot water temperature is 100 ~ 150 DEG C, and injection rate is 120 ~ 150t/d;
Described flue gas injection rate is the hot water injection rate of 1.0 ~ 2.0 (subsurface volumes);
Described oil-soluble viscosity reducer is the sulfonate of many aromatic rings molecular structure and the compound system of carboxylate;
Described oil-soluble viscosity reducer is SLS-5 or CR-1 or is prepared the thinner of gained by 0.35wt.% host petroleum sulfonate PS-4 and 0.2wt.% auxiliary agent amide-type non-ionic surface active agent CMA or prepared the thinner of gained by 0.3% anion surfactant and 0.2% non-ionic surfactant OP-10.
The injection rate of described oil-soluble viscosity reducer solution is the hot water injection rate of 0.5% ~ 1.0% (quality);
The mass concentration of described oil-soluble viscosity reducer solution is 300000 ~ 600000mg/L.
The present invention can provide a kind of new method of cost-effective raising oil recovery factor for common heavy oil reservoir development late stage after water drive, be applicable to have comparatively active edge-bottom water, be applicable to oil reservoir comprehensive water cut higher than 90%, oil reservoir recovery percent of reserves is lower than 30%, viscosity of crude scope is between 150 ~ 1000mPas, and water oil volume is than the oil reservoir being greater than 10.
The present invention be directed to that viscosity of crude is high, edge-bottom water enliven, common heavy oil reservoir after all unconformable water drive of chemical flooding and steam flooding, be develop under current technical background can increase substantially water drive after the new technique of common heavy oil reservoir oil recovery factor.In hot water flooding's process, injection of flue gas and high temperature resistant oil-soluble viscosity reducer, effectively reduce viscosity of crude, improves oil displacement efficiency.After the raising water drive be made up of hot water, flue gas, thinner, the method for common heavy oil reservoir recovery ratio reduces viscosity of crude by heat, gas, chemically composited effect, expand sweep area, water drive conventional in oil reservoir can not a large amount of remaining oils of extraction be displaced, thus recovery factor of heavy oil reservoir 26.4% after increasing substantially water drive, oil reservoir ultimate recovery can reach 48.8%.The flue gas produced of simultaneously burning directly injects underground, can improve the thermal efficiency more than 10%, reduces environment pollution.
Accompanying drawing explanation
Fig. 1 is oil-soluble viscosity reducer viscosity reduction process schematic;
Fig. 2 is oil-soluble viscosity reducer viscosity reduction feature schematic diagram.
Detailed description of the invention
For making above and other object of the present invention, feature and advantage can become apparent, cited below particularly go out preferred embodiment be described in further detail as follows.
Embodiment 1:
A. inject the hot water of 0.2 times of formation pore volume and the mixture of flue gas with the speed of 150t/d, wherein hot water temperature is 150 DEG C;
B. oil-soluble viscosity reducer SLS-5 (0.35wt.% host petroleum sulfonate PS-4+0.2wt.% auxiliary agent amide-type non-ionic surface active agent CMA) is mixed with the solution of 500000mg/L, injects water injection well 5d with hot water and flue gas mixture in the injection rate of 0.6t/d companion a;
C. hot water and flue gas mixture 60d is injected with the speed of 150t/d.
D. step b, c is repeated.
Embodiment 2:
A. inject the hot water of 0.2 times of formation pore volume and the mixture of flue gas, wherein hot water injection rate is 150t/d, temperature 100 DEG C, and flue gas injection rate is 300t/d;
B. oil-soluble viscosity reducer (0.3% anion surfactant+0.2% non-ionic surfactant OP-10) is mixed with the solution of 600000mg/L, injects water injection well 5d with hot water and flue gas mixture in the injection rate of 1.5t/d companion a;
C. hot water and flue gas mixture 60d is injected with the speed of 150t/d.
D. step b, c is repeated.
Embodiment 3:
A. the hot water of 0.15 times of formation pore volume and the mixture of flue gas is injected with the speed of 120t/d;
B. oil-soluble viscosity reducer CR-1 (non-ionic surface active agent+alkali+auxiliary agent) is mixed with the solution of 300000mg/L, injects water injection well 10d with hot water and flue gas mixture in the injection rate of 1.2t/d companion a;
C. hot water and flue gas mixture 80d is injected with the flue gas injection rate of the hot water injection rate of 120t/d and 240t/d.
D. step b, c is repeated.
Claims (8)
1. improve a method for common heavy oil reservoir recovery ratio after water drive, it is characterized in that carrying out as follows:
A. the hot water of 0.15 ~ 0.2 times of formation pore volume and the mixture of flue gas is injected;
B. oil-soluble viscosity reducer solution is injected water injection well 5 ~ 10d;
C. hot-water flooding and flue gas mixture 60 ~ 80d;
D. step b, c is repeated.
2. the method for common heavy oil reservoir recovery ratio after raising water drive according to claim 1, it is characterized in that, described hot water temperature is 100 ~ 150 DEG C, and injection rate is 120 ~ 150t/d.
3. the method for common heavy oil reservoir recovery ratio after raising water drive according to claim 1, it is characterized in that, described flue gas injection rate is 1.0 ~ 2.0 (subsurface volume) hot water injection rate.
4. the method for common heavy oil reservoir recovery ratio after raising water drive according to claim 1, it is characterized in that, oil-soluble viscosity reducer described in step b is the sulfonate of many aromatic rings molecular structure and the compound system of carboxylate.
5. the method for common heavy oil reservoir recovery ratio after raising water drive according to claim 4, it is characterized in that, described oil-soluble viscosity reducer is SLS-5 or CR-1 or is prepared the thinner of gained by 0.35wt.% host petroleum sulfonate PS-4 and 0.2wt.% auxiliary agent amide-type non-ionic surface active agent CMA or prepared the thinner of gained by 0.3% anion surfactant and 0.2% non-ionic surfactant OP-10.
6. the method for common heavy oil reservoir recovery ratio after raising water drive according to claim 1, it is characterized in that, the injection rate of oil-soluble viscosity reducer solution described in step b is 0.5% ~ 1.0% (quality) hot water injection rate.
7. the method for common heavy oil reservoir recovery ratio after raising water drive according to claim 1, it is characterized in that, described in step b, the mass concentration of oil-soluble viscosity reducer solution is 300000 ~ 600000mg/L.
8. the composite heat carrier according to the arbitrary claim of claim 1-7 improves the method for recovery factor of heavy oil reservoir, it is characterized in that, described method is applicable to oil reservoir comprehensive water cut higher than 90%, oil reservoir recovery percent of reserves is lower than 30%, viscosity of crude scope is between 150 ~ 1000mPas, have comparatively active edge-bottom water, water oil volume is than the oil reservoir being greater than 10.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201410194080.9A CN105089590A (en) | 2014-05-08 | 2014-05-08 | Method for improving yield of common heavy oil reservoir after water flooding |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201410194080.9A CN105089590A (en) | 2014-05-08 | 2014-05-08 | Method for improving yield of common heavy oil reservoir after water flooding |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN105089590A true CN105089590A (en) | 2015-11-25 |
Family
ID=54570823
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201410194080.9A Pending CN105089590A (en) | 2014-05-08 | 2014-05-08 | Method for improving yield of common heavy oil reservoir after water flooding |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN105089590A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| 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 |
Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CA1197457A (en) * | 1983-01-18 | 1985-12-03 | Winston R. Shu | Viscous oil recovery method |
| US20050022989A1 (en) * | 1999-05-07 | 2005-02-03 | Ionics, Incorporated | Water treatment method for heavy oil production |
| CN101839127A (en) * | 2010-04-12 | 2010-09-22 | 北京东方亚洲石油技术服务有限公司 | Exploitation method of thick oil type oil deposit |
| CN101839123A (en) * | 2010-03-26 | 2010-09-22 | 北京东方亚洲石油技术服务有限公司 | Exploitation method for wax precipitation oil reservoir |
| CN102618239A (en) * | 2011-12-28 | 2012-08-01 | 中国石油天然气股份有限公司 | Salt- and temperature-resistant emulsification viscosity reducer for heavy oil |
| CN104213886A (en) * | 2014-08-19 | 2014-12-17 | 中国石油天然气股份有限公司 | Heavy oil reservoir artificial bubble oil throughput exploiting method |
-
2014
- 2014-05-08 CN CN201410194080.9A patent/CN105089590A/en active Pending
Patent Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CA1197457A (en) * | 1983-01-18 | 1985-12-03 | Winston R. Shu | Viscous oil recovery method |
| US20050022989A1 (en) * | 1999-05-07 | 2005-02-03 | Ionics, Incorporated | Water treatment method for heavy oil production |
| CN101839123A (en) * | 2010-03-26 | 2010-09-22 | 北京东方亚洲石油技术服务有限公司 | Exploitation method for wax precipitation oil reservoir |
| CN101839127A (en) * | 2010-04-12 | 2010-09-22 | 北京东方亚洲石油技术服务有限公司 | Exploitation method of thick oil type oil deposit |
| CN102618239A (en) * | 2011-12-28 | 2012-08-01 | 中国石油天然气股份有限公司 | Salt- and temperature-resistant emulsification viscosity reducer for heavy oil |
| CN104213886A (en) * | 2014-08-19 | 2014-12-17 | 中国石油天然气股份有限公司 | Heavy oil reservoir artificial bubble oil throughput exploiting method |
Non-Patent Citations (1)
| Title |
|---|
| 张凤英等: "《稠油油溶性降粘剂研究进展》", 《特种油气藏》 * |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| 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 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN102767356B (en) | Method for using combustion and vapor combination flooding to exploit thick oil | |
| CN102587877B (en) | Multi-element thermal fluid displacement process | |
| Taber et al. | EOR screening criteria revisited—Part 1: Introduction to screening criteria and enhanced recovery field projects | |
| CN104059625B (en) | Method for preparing high-stability heat-resistance and salt-tolerance air foam oil displacing agent | |
| CN101004132A (en) | Exploitation technique for disgorging thick oil by pouring air to assistant steam | |
| CN102230372A (en) | Thermal recovery technology of multielement thermal fluid of thickened oil well | |
| CN102242626A (en) | Steam drive exploitation method for heavy oil reservoir | |
| CN100398779C (en) | Hot air filling balance oil recovery technique 'zhanqian' mountain oil reservoir | |
| CN101539012A (en) | Stratum catalytic oxidation thick oil thermal recovery method | |
| CN102061906A (en) | Air foam slug flow driving process for oil recovery of oil field | |
| CN101122227A (en) | Fire flooding oil extraction crude oil combustion-assistant ignition process | |
| CN105041275A (en) | Oil extraction method for reducing oxygen concentration of associated gas of production well by injecting oxygen reduction air | |
| CN113982546B (en) | Evaluation method for carbon dioxide injection profile of horizontal well | |
| CN102392623B (en) | Air-drive oil production method for low-permeability reservoir | |
| CN102644454A (en) | Method for increasing recovery ratio of thick oil | |
| CN106761627A (en) | One kind adjusts the stifled row of helping economic benefits and social benefits to aid in viscous crude to handle up development approach | |
| CN104929597A (en) | Horizontal well chemical flooding mining method | |
| CN103410489A (en) | Modification and viscosity reduction method for in-situ combustion heavy oil recovery | |
| CN104632161A (en) | Multiple thermal fluid composite system oil displacing method | |
| CN102587878A (en) | Multi-element thermal fluid auxiliary gravitational displacement process | |
| CN101864936A (en) | Authigenic carbon dioxide oil displacement recovery ratio technology in oil layer | |
| CN103628846A (en) | Method for improving CO2 displacement efficiency of low-permeability reservoir | |
| CN102977876B (en) | Guar gum fracturing fluid with ultralow concentration and low-temperature coal-bed gas well fracturing method | |
| CN103289665B (en) | Displacement composition, containing its multielement hot fluid displacement composition and displacement method | |
| CN103541708A (en) | Method for improving super-heavy oil steam flooding recovery efficiency |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| WD01 | Invention patent application deemed withdrawn after publication |
Application publication date: 20151125 |
|
| WD01 | Invention patent application deemed withdrawn after publication |