CN103510932A - Chemical cold-production method applicable to medium-deep low-permeability heavy oil reservoir - Google Patents
Chemical cold-production method applicable to medium-deep low-permeability heavy oil reservoir Download PDFInfo
- Publication number
- CN103510932A CN103510932A CN201210202121.5A CN201210202121A CN103510932A CN 103510932 A CN103510932 A CN 103510932A CN 201210202121 A CN201210202121 A CN 201210202121A CN 103510932 A CN103510932 A CN 103510932A
- Authority
- CN
- China
- Prior art keywords
- oil
- reservoir
- carbon dioxide
- microemulsion
- permeability
- 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
Landscapes
- Colloid Chemistry (AREA)
Abstract
The invention provides a chemical cold-production method applicable to a medium and deep stratum low-permeability heavy oil reservoir. The method includes the first step of selecting a medium-deep low-permeability heavy oil reservoir, wherein the depth of the selected oil layer is 1500-2800m, the permeability of the selected oil layer is smaller than or equal to 50*10-3 square microns, the total thickness of the selected oil layer is larger than or equal to 3.0m, the total net thickness ratio of the selected oil layer is larger than or equal to 0.3, the porosity of the selected oil layer is larger than or equal to 0.10, and the permeability variation coefficient of the selected oil layer is small than or equal to 0.8, the second step of squeezing microemulsion viscosity reduction systems and liquid carbon dioxide into the selected oil layer alternately in a staged plugging mode, the third step of carrying out well shut-in, well soaking, well opening and blowout prevention, and the fourth step of continuing extracting oil through a downhole pump. The chemical cold-production method has the advantages that microemulsion can enable crude oil to be stripped to be oil droplets with hydrophilic surfaces, heavy oil spontaneously diffuses on the surface of system water solution, carbon dioxide has functions of reducing viscosity and increasing energy can enlarge the viscosity reduction radius of the microemulsion, the water recovery rate is improved, and the output and the recovery efficiency of the medium-deep low-permeability heavy oil through a synergistic effect are improved.
Description
Technical field
The present invention relates to oilfield exploitation technical field, is a kind of mid-deep strata hyposmosis heavy crude reservoir that is applicable to, and improves the mid-deep strata hyposmosis heavy crude reservoir chemistry exploitation method of rate of oil production and recovery ratio.
Background technology
Mid-deep strata hyposmosis heavy crude reservoir, i.e. reservoir buried depth 1500～2800m, permeability<50 * 10<sup TranNum="72">-3</sup>um<sup TranNum="73">2</sup>heavy crude reservoir.For this class oil reservoir, because viscosity of crude is high, waterflooding extraction does not reach effect.And if adopt the method for steam injection, because oil reservoir is darker, heat waste is serious, and Reservoir Permeability is low, causes steam injection pressure high, or notes not enter.
For hyposmosis deep-layer heavy crude, adopt in advance that pressure break viscosity reducing is coldly adopted, later stage heat extraction by steam injection matched process technology has good development effectiveness.138 pages of " deep-layer heavy crude exploitation supporting technology is in the application study of Shengli Oil Field " petroleum gas journal the 33rd the 4th phases of volume of April in 2011.
Chemistry auxiliary steam send in and out is mainly to utilize the one matters such as expansion-resisting agent, conventional thinner, air, nitrogen or carbon dioxide or combination of two auxiliary steam to handle up.The patent No. is the carbon dioxide assisted steam flooding exploitation deep-layer heavy crude method of CN101139923A, these class methods are mainly used in the steam drive oil production in steam soak later stage, the necessary viscosity of crude of applicable reservoir condition is low, and oil recovery conventional steam is handled up and can be obtained ideal effect.
The patent No. is the thermochemistry auxiliary reinforced steam flooding method of CN101255788A, and these class methods are utilized oil-soluble viscosity reducer and carbon dioxide auxiliary water horizontal well Simulation on whole pay zones, and development cost is higher.
Publication number is a kind of deep low penetrating thin oil reservoir fire flooding oil production firing method of CN1888381A, is suitable for the exploitation of ligh-oil reservoir.
Most all for thermal recovery in mid-deep strata heavy crude reservoir exploitation method, for the cold technology of adopting, dabble seldom, thermal process field conduct difficulty is large, and cost is also high, explore the cold economical and effective development mode of adopting of mid-deep strata low-permeability oil deposit chemistry, improve its reserves development degree and recovery ratio.
Summary of the invention
Object of the present invention is exactly in view of the foregoing defects the prior art has, and a kind of cold exploitation method of adopting of mid-deep strata hyposmosis chemistry that is applicable to is provided, and can reduce viscosity of crude, reduces profit mobility ratio, extends productive life, improves production effect.
Object of the present invention can be achieved by the following technical measures:
The method is carried out as follows:
A. select reservoir depth 1500～2800m, permeability≤50 * 10
-3um
2, oil reservoir gross thickness>=3.0m, clean gross thickness ratio>=0.3, oil reservoir degree of porosity>=0.10, the mid-deep strata hyposmosis heavy crude reservoir of coefficient of permeability variation≤0.8;
B. to selected oil reservoir squeezing microemulsion viscosity reduction system+liquid carbon dioxide, microemulsion viscosity reduction system and liquid carbon dioxide alternately inject with the form of minute slug, through closing well, stewing well 4-7 days, drive a well after blowout prevention, lower pump recovers the oil continuously, when within instantaneous day, produce oil drops to economic boundaries, start cold the adopting of next round chemistry, so loop.
Object of the present invention also can be achieved by the following technical measures:
Described microemulsion viscosity reduction system injection rate is 0.05～0.1t/m, and injection rate is 20～30m
3/ h; Described liquid carbon dioxide injection rate is 0.75～1.5t/m, and injection rate is 10～20m
3/ h; It is to be divided into 4～6 slugs that the form of described minute slug is alternately injected, and first to oil reservoir, clamp-ons microemulsion viscosity reduction system and clamp-ons liquid carbon dioxide again, and sequence alternate carries out successively.
Microemulsion injects after oil well, and microemulsion coexists with excessive water and excessive oily balance, and two alternate interfacial tensions reach ultralow, the interfacial tension 50mN/m between crude oil and water conventionally, and after formation microemulsion phase, its interfacial tension can be reduced to 10
-2～10
-4mN/m, reduces former oil viscosity significantly, increases its mobility, and the crude oil that makes to residue in rock flows into oil well, thereby increases the recovery ratio of crude oil, reaches the object that in-depth is recovered the oil.
Effect of the present invention is as follows:
1) microemulsion is peeled off into crude oil the oil droplet of surface hydrophilic, and viscous crude is in the spontaneous diffusion in surface of the system aqueous solution;
2) carbon dioxide has viscosity reduction energy increasing function, and expands microemulsion viscosity reduction radius, improves water recovery rate;
3), by synergy, improve mid-deep strata hyposmosis heavy oil production and recovery ratio.
Be below that reservoir water flooding is tested contrast table with the thing mould of squeezing microemulsion viscosity reduction system+liquid carbon dioxide
| Project | Water drive | Squeezing microemulsion viscosity reduction system+liquid carbon dioxide |
| Residual oil saturation, % | 67.8 | 53.5 |
| Oil displacement efficiency, % | 22.9 | 39.2 |
Laboratory experiment result shows: squeezing microemulsion viscosity reduction system+liquid carbon dioxide has obviously increased displacement pressure reduction, has improved displacement efficiency, wherein squeezes microemulsion viscosity reduction system+liquid carbon dioxide and improves displacement efficiency more than 15%.
The specific embodiment
The present invention is to provide the chemical exploitation method of mid-deep strata hyposmosis heavy crude reservoir, this class oil reservoir is adopted to the present invention, squeezing microemulsion viscosity reduction system+liquid carbon dioxide, microemulsion is peeled off into crude oil the oil droplet of surface hydrophilic, and viscous crude is in the spontaneous diffusion in surface of the system aqueous solution; Carbon dioxide has viscosity reduction energy increasing function, and expands microemulsion viscosity reduction radius, improves water recovery rate, by composite synergy, improves mid-deep strata hyposmosis heavy oil production and recovery ratio, and this class oil reservoir is effectively employed.
Embodiment 1:
Selecting certain oil field deeply buried reservoir degree is 2800m, permeability 0.12 * 10
-3um
2, oil reservoir gross thickness is 3.9m, and clean gross thickness is than 0.3, and unit reserve factor is 14.1 * 10
4t/km
2.m, oil reservoir degree of porosity 0.10, the mid-deep strata hyposmosis heavy crude reservoir ，50℃ ground viscosity of crude 11525mPas of coefficient of permeability variation≤0.8 is special heavy crude reservoir;
To selected oil reservoir, according to injection rate, be that 0.05t/m, injection rate are 30m
3/ h squeezes microemulsion viscosity reduction system and is that 0.75t/m, injection rate are 20m according to injection rate
3/ h squeezes liquid carbon dioxide, microemulsion viscosity reduction system and liquid carbon dioxide are with minute 6 slug squeezings, first to oil reservoir, clamp-on microemulsion viscosity reduction system and clamp-on again liquid carbon dioxide, sequence alternate carries out successively, through closing well, stewing well 7 days, drive a well after blowout prevention, lower pump recovers the oil continuously, starts cold the adopting of next round chemistry when within instantaneous day, produce oil drops to economic boundaries.
For reservoir geology feature, oil property and development contradiction, this block in 2011, on the basis of formation testing in early stage, has been carried out squeezing microemulsion viscosity reduction system+liquid carbon dioxide compound system chemistry extracting experiment.
1, parameter designing
According to reservoir geology situation and numerical simulation result, design microemulsion viscosity reduction system 800m
3, liquid carbon dioxide 300t, design parameter is as follows:
1) microemulsion injection parameter
Total injection 20t, is configured to 2.5% aqueous solution, amounts to 800m
3.
2) liquid carbon dioxide injection parameter
Injection rate is 300t altogether.
2, injection mode
First inject microemulsion 160m
3, then inject the liquid CO of 60t
2, then alternately inject 120m
3the liquid CO of microemulsion and 60t
2, finally inject microemulsion 160m
3, refer to following table.
| Project | Slug 1 | Slug 2 | Slug 3 | Slug 4 | Slug 5 | Slug 6 |
| Microemulsion (m 3） | 160 | 120 | 120 | 120 | 120 | 160 |
| Liquid CO 2（t） | 60 | 60 | 60 | 60 | 60 | ? |
Implement after the present invention, this block individual well daily oil production is greater than 10t/d, has realized effectively employing of this block.
Embodiment 2:
Selecting certain oil field deeply buried reservoir degree is 1500m, permeability 50 * 10
-3um
2, oil reservoir gross thickness is 3.0m, and clean gross thickness is than 0.5, and unit reserve factor is 14.1 * 10
4t/km
2.m, oil reservoir degree of porosity 0.20, the mid-deep strata hyposmosis heavy crude reservoir of coefficient of permeability variation≤0.2, this block viscosity of crude scope is large, is up to 20 * 10
4mPas, has 7987 * 10
4t deep-layer heavy crude prognostic reserves use prior art to be difficult to employ.For such oil reservoir, also do not have at present theory and field experiment experience can supply to use for reference both at home and abroad, its development difficulty is quite large.These characteristics causes mid-deep strata hyposmosis heavy crude reservoir unanimously not obtain commercial oil, has affected reserves upgrading and has employed.
To selected oil reservoir, according to injection rate, be that 0.1t/m, injection rate are 20m
3/ h squeezes microemulsion viscosity reduction system and is that 1.5t/m, injection rate are 10m according to injection rate
3/ h squeezes liquid carbon dioxide, microemulsion viscosity reduction system and liquid carbon dioxide are with minute 4 slug squeezings, first to oil reservoir, clamp-on microemulsion viscosity reduction system and clamp-on again liquid carbon dioxide, sequence alternate carries out successively, through closing well, stewing well 4 days, drive a well after blowout prevention, lower pump recovers the oil continuously, starts cold the adopting of next round chemistry when within instantaneous day, produce oil drops to economic boundaries.
For reservoir geology feature, oil property and development contradiction, this block in 2011, on the basis of formation testing in early stage, has been carried out squeezing microemulsion viscosity reduction system+liquid carbon dioxide compound system chemistry extracting experiment.
According to reservoir geology situation and numerical simulation result, design microemulsion system 1000m
3, liquid carbon dioxide 400t, design parameter is as follows:
1) microemulsion injection parameter
Total injection 25t, is configured to 2.5% aqueous solution, amounts to 1000m
3, minute 4 slugs.
2) liquid carbon dioxide injection parameter
Injection rate is 400t altogether, minute 8 slugs.
Implement after the present invention, this block individual well daily oil production is greater than 12t/d, has realized effectively employing of this block.
Claims (4)
1. be applicable to the cold mining method of mid-deep strata hyposmosis heavy crude reservoir chemistry, it is characterized in that the method carries out as follows:
A. select reservoir depth 1500～2800m, permeability≤50 * 10
-3um
2, oil reservoir gross thickness>=3.0m, clean gross thickness ratio>=0.3, oil reservoir degree of porosity>=0.10, the mid-deep strata hyposmosis heavy crude reservoir of coefficient of permeability variation≤0.8;
B. to selected oil reservoir squeezing microemulsion viscosity reduction system+liquid carbon dioxide, microemulsion viscosity reduction system and liquid carbon dioxide alternately inject with the form of minute slug, through closing well, stewing well 4-7 days, drive a well after blowout prevention, lower pump recovers the oil continuously, starts cold the adopting of next round chemistry when within instantaneous day, produce oil drops to economic boundaries.
2. a kind of cold mining method of mid-deep strata hyposmosis heavy crude reservoir chemistry that is applicable to according to claim 1, is characterized in that described microemulsion viscosity reduction system injection rate is 0.05～0.1t/m, and injection rate is 20～30m
3/ h.
3. a kind of cold mining method of mid-deep strata hyposmosis heavy crude reservoir chemistry that is applicable to according to claim 1, is characterized in that described liquid carbon dioxide injection rate is 0.75～1.5t/m, and injection rate is 10～20m
3/ h.
4. according to a kind of cold mining method of mid-deep strata hyposmosis heavy crude reservoir chemistry that is applicable to described in claim 1 or 2 or 3, it is characterized in that it is to be divided into 4～6 slugs that the described form of dividing slug is alternately injected, first to oil reservoir, clamp-on microemulsion viscosity reduction system and clamp-on liquid carbon dioxide again, sequence alternate carries out successively.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201210202121.5A CN103510932A (en) | 2012-06-19 | 2012-06-19 | Chemical cold-production method applicable to medium-deep low-permeability heavy oil reservoir |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201210202121.5A CN103510932A (en) | 2012-06-19 | 2012-06-19 | Chemical cold-production method applicable to medium-deep low-permeability heavy oil reservoir |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN103510932A true CN103510932A (en) | 2014-01-15 |
Family
ID=49894297
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201210202121.5A Pending CN103510932A (en) | 2012-06-19 | 2012-06-19 | Chemical cold-production method applicable to medium-deep low-permeability heavy oil reservoir |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN103510932A (en) |
Cited By (11)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| 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 |
| 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 |
| 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 |
| CN106194133A (en) * | 2016-07-20 | 2016-12-07 | 西南石油大学 | A kind of determination method of chemical viscosity reduction boundary of works area |
| CN107859507A (en) * | 2016-09-22 | 2018-03-30 | 中国石油化工股份有限公司 | Improve the method for increasing of oil well single well productivity |
| CN107893648A (en) * | 2017-12-19 | 2018-04-10 | 北京百利时能源技术股份有限公司 | The cold mining method of heavy crude reservoir carbon dioxide accumulation of energy high pressure viscosity reduction |
| CN113803037A (en) * | 2020-06-12 | 2021-12-17 | 中国石油化工股份有限公司 | Deep low-permeability thickened oil fluidity regulation and control displacement development method |
| CN113882840A (en) * | 2021-11-12 | 2022-01-04 | 浙江工业大学 | Method for heavy oil huff-puff cold recovery by using raw nano material |
| CN114059978A (en) * | 2020-08-03 | 2022-02-18 | 中国石油化工股份有限公司 | Chemical cold-production method for strong water-sensitive heavy oil reservoir |
| CN115045642A (en) * | 2022-05-20 | 2022-09-13 | 常州大学 | Well and oil well push-pull linkage thickened oil 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 |
-
2012
- 2012-06-19 CN CN201210202121.5A patent/CN103510932A/en active Pending
Non-Patent Citations (1)
| Title |
|---|
| 余五星: "超稠油蒸汽吞吐井注入CO_2相态变化及热能消耗研究", 《中外能源》 * |
Cited By (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| 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 |
| 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 |
| 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 |
| CN106194133A (en) * | 2016-07-20 | 2016-12-07 | 西南石油大学 | A kind of determination method of chemical viscosity reduction boundary of works area |
| CN107859507A (en) * | 2016-09-22 | 2018-03-30 | 中国石油化工股份有限公司 | Improve the method for increasing of oil well single well productivity |
| CN107893648A (en) * | 2017-12-19 | 2018-04-10 | 北京百利时能源技术股份有限公司 | The cold mining method of heavy crude reservoir carbon dioxide accumulation of energy high pressure viscosity reduction |
| CN113803037A (en) * | 2020-06-12 | 2021-12-17 | 中国石油化工股份有限公司 | Deep low-permeability thickened oil fluidity regulation and control displacement development method |
| CN113803037B (en) * | 2020-06-12 | 2023-03-28 | 中国石油化工股份有限公司 | Deep low-permeability thickened oil fluidity regulation and control displacement development method |
| CN114059978A (en) * | 2020-08-03 | 2022-02-18 | 中国石油化工股份有限公司 | Chemical cold-production method for strong water-sensitive heavy oil reservoir |
| CN114059978B (en) * | 2020-08-03 | 2024-05-07 | 中国石油化工股份有限公司 | Chemical cold recovery method for strong water-sensitive heavy oil reservoir |
| 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 |
| CN113882840A (en) * | 2021-11-12 | 2022-01-04 | 浙江工业大学 | Method for heavy oil huff-puff cold recovery by using raw nano material |
| CN115045642A (en) * | 2022-05-20 | 2022-09-13 | 常州大学 | Well and oil well push-pull linkage thickened oil exploitation method |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN103510932A (en) | Chemical cold-production method applicable to medium-deep low-permeability heavy oil reservoir | |
| Alagorni et al. | An overview of oil production stages: enhanced oil recovery techniques and nitrogen injection | |
| Taber et al. | EOR screening criteria revisited—Part 1: Introduction to screening criteria and enhanced recovery field projects | |
| Chang et al. | Advances in polymer flooding and alkaline/surfactant/polymer processes as developed and applied in the People's Republic of China | |
| CN101255788B (en) | Thermochemistry auxiliary reinforced steam flooding method | |
| CN109653721B (en) | Fracturing and energy-increasing oil displacement integrated process method for shallow low-pressure low-permeability oil reservoir | |
| CN105822276B (en) | Interval while water injection oil extraction method between multistage fracturing horizontal well seam | |
| Ocampo et al. | Successful foam EOR pilot in a mature volatile oil reservoir under miscible gas injection | |
| MX2011003125A (en) | Method for recovering heavy/viscous oils from a subterranean formation. | |
| WO2015191864A1 (en) | Liquid oil production from shale gas condensate reservoirs | |
| WO2013059909A1 (en) | Steam flooding with oxygen injection, and cyclic steam stimulation with oxygen injection | |
| CN106437642A (en) | Fractured reservoir horizontal well injection-production asynchronous exploitation method | |
| CN106634922A (en) | Self generated gas foam oil-displacing agent liquid and application and injection increase and yield increase method thereof | |
| CN209483309U (en) | Airlift unit | |
| CN101691838A (en) | Ultralow permeability oil filed water injection well multicomponent chemical microemulsion pressure reduction and injection gain method | |
| CN114439440A (en) | Viscosity reduction pressure flooding method for deep low-permeability heavy oil reservoir | |
| RU2297524C2 (en) | Method for treatment of a deposit of highly viscous oil | |
| CN110439528B (en) | Carbon dioxide acid fracturing method for low-permeability heterogeneous carbonate rock gas reservoir | |
| CN108397171A (en) | A kind of nitrogen auxiliary carbon dioxide is handled up the method for the fine and close oil of exploitation | |
| Dong et al. | The thermal recovery methods and technical limits of Bohai offshore heavy oil reservoirs: A case study | |
| Elbaloula et al. | The challenges of cyclic steam stimulation (CSS) to enhanced oil recovery (EOR) in Sudanese oil field | |
| Zhang et al. | Foam flooding technology used for enhanced oil recovery in offshore oilfields of china’s bohai bay | |
| CN114607328A (en) | Method for exploiting thick oil by huff and puff through low-temperature oxidation air injection assisted by solvent | |
| Martinez et al. | A new practical water injection system in offshore fields | |
| Wu et al. | Optimization of field-scale surface dissolution with thermoelastic constraints |
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 | ||
| WD01 | Invention patent application deemed withdrawn after publication |
Application publication date: 20140115 |