CN108729893B - Foam composite cold recovery method for improving recovery ratio of heavy oil reservoir - Google Patents
Foam composite cold recovery method for improving recovery ratio of heavy oil reservoir Download PDFInfo
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- 238000011084 recovery Methods 0.000 title claims abstract description 57
- 239000006260 foam Substances 0.000 title claims abstract description 47
- 239000002131 composite material Substances 0.000 title claims abstract description 45
- 239000000295 fuel oil Substances 0.000 title claims abstract description 33
- 238000000034 method Methods 0.000 title claims abstract description 21
- 239000003921 oil Substances 0.000 claims abstract description 91
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 74
- 229920000642 polymer Polymers 0.000 claims abstract description 54
- 238000002347 injection Methods 0.000 claims abstract description 44
- 239000007924 injection Substances 0.000 claims abstract description 44
- 238000006073 displacement reaction Methods 0.000 claims abstract description 32
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 25
- 239000007788 liquid Substances 0.000 claims description 24
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 22
- 239000011148 porous material Substances 0.000 claims description 20
- 239000004088 foaming agent Substances 0.000 claims description 17
- 229910052757 nitrogen Inorganic materials 0.000 claims description 11
- 239000012452 mother liquor Substances 0.000 claims description 10
- 239000007789 gas Substances 0.000 claims description 9
- 238000005187 foaming Methods 0.000 claims description 8
- 239000012530 fluid Substances 0.000 claims description 7
- 229920002401 polyacrylamide Polymers 0.000 claims description 6
- 239000011259 mixed solution Substances 0.000 claims description 5
- 238000005086 pumping Methods 0.000 claims description 5
- 239000010865 sewage Substances 0.000 claims description 5
- 230000000694 effects Effects 0.000 abstract description 5
- 238000010438 heat treatment Methods 0.000 abstract description 4
- 238000005516 engineering process Methods 0.000 description 14
- 239000010779 crude oil Substances 0.000 description 8
- 238000012360 testing method Methods 0.000 description 5
- 238000011161 development Methods 0.000 description 4
- 230000018109 developmental process Effects 0.000 description 4
- 238000004088 simulation Methods 0.000 description 4
- 239000000243 solution Substances 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 3
- 230000009467 reduction Effects 0.000 description 3
- 238000012546 transfer Methods 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 150000001875 compounds Chemical class 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 description 1
- 238000010797 Vapor Assisted Petroleum Extraction Methods 0.000 description 1
- 239000003513 alkali Substances 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 229910001424 calcium ion Inorganic materials 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000000052 comparative effect Effects 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 239000012535 impurity Substances 0.000 description 1
- 229910001425 magnesium ion Inorganic materials 0.000 description 1
- 238000013048 microbiological method Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
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- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
- E21B43/168—Injecting a gaseous medium
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/20—Displacing by water
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Abstract
The invention belongs to the technical field of heavy oil recovery, and particularly relates to a foam composite cold recovery method for improving the recovery ratio of a heavy oil reservoir, which mainly comprises the following steps: alternately injecting the thick oil viscosity-reducing oil displacement agent, water and the polymer composite foam oil displacement system into a water injection well, and then performing water flooding; the method can effectively improve the recovery ratio of the thickened oil under the non-heating condition, has the effect of improving the recovery ratio by more than 15 percent, integrates different thickened oil recovery methods, can lay a technical foundation for the complex subsequent recovery of the thickened oil deposit, provides guarantee, and has very important practical significance for developing the thickened oil deposit in the oil field.
Description
Technical Field
The invention belongs to the technical field of heavy oil recovery, and particularly relates to a foam composite cold recovery method for improving the recovery efficiency of a heavy oil reservoir, which is suitable for the conditions that the temperature of the reservoir is not higher than 80 ℃, the mineralization degree is lower than 20000mg/l, the concentration of calcium and magnesium ions is lower than 500mg/l, the viscosity of underground crude oil is lower than 5000mPa & s, and the permeability is 500 × 10-3µm2～50000×10-3µm2Of the reservoir.
Background
At present, most oil fields in the east of China enter the later development stage, the production increase difficulty is high, the recovery ratio of heavy oil reservoirs is relatively low, and the potential is large. The reserve of the thick oil in China is large and the distribution is wide, and the exploitation of the thick oil reservoir is more important under the condition that the conventional crude oil is limited by the increase of the reserve. The thick oil has large viscosity and poor flowing capability, and the development effect of the thick oil is poor by the conventional exploitation technical means.
As for the current thick oil recovery technology, the technology can be divided into two major parts: thermal recovery and cold recovery. The thermal recovery technology mainly comprises the following steps: the heavy oil thermal recovery technology mainly has the problems of high cost, short effective time and poor economic benefit. The cold production technology mainly comprises an alkali flooding technology, a polymer flooding technology, a microbiological method, a VAPEX technology and the like, and has the problems of adaptability and cost respectively, so that the large-scale popularization and application are limited to a certain extent. How to reduce the cost under the condition of low oil price, improve the development effect of the heavy oil reservoir and increase the recoverable reserve is a problem which needs to be solved urgently by petroleum workers.
The oil deposit has certain complexity in the aspect of geology, the heavy oil fluid has certain variability, and various single heavy oil development modes have self limitations. Therefore, a proper heavy oil exploitation technology is selected according to different actual conditions, or multiple exploitation technologies are comprehensively utilized, so that the self limitation of one exploitation technology is overcome, and the improvement of the crude oil recovery rate is promoted.
The foam compound oil displacement technology for cold recovery of the heavy oil can fully exert the characteristics that the viscosity reduction oil displacement agent for the heavy oil reduces the viscosity of the crude oil, improves the fluidity of the heavy oil and improves the swept area of a compound foam system, and is a new technology which has wide application prospect and can greatly improve the crude oil recovery rate of a heavy oil reservoir under the background of the prior art.
Disclosure of Invention
The invention aims to solve the limitation of a single oil extraction technology in the prior art, provides a foam composite cold recovery method for improving the recovery ratio of a heavy oil reservoir, can effectively improve the recovery ratio of the heavy oil under a non-heating condition, integrates different heavy oil recovery methods, can lay a technical foundation for the complex subsequent recovery of the heavy oil reservoir, provides guarantee, and has very important practical significance for developing the heavy oil reservoir in an oil field.
The purpose of the invention can be realized by the following technical scheme:
a foam composite cold recovery method for improving the recovery ratio of a heavy oil reservoir comprises the steps of alternately injecting a heavy oil viscosity-reducing oil displacement agent, water and a polymer composite foam oil displacement system into a water injection well, and then carrying out water displacement.
The purpose of the invention can be realized by the following technical scheme:
the foam composite cold recovery method for improving the recovery ratio of the heavy oil reservoir comprises the following steps:
(1) water is driven until the comprehensive water content is more than 95 percent;
(2) injecting a thick oil viscosity-reducing oil-displacing agent into the water injection well, wherein the volume of the thick oil viscosity-reducing oil-displacing agent is 0.03-0.05 times of the pore volume of the oil reservoir;
(3) the water flooding well injects water to recover water drive, the water injection volume is 0.03-0.05 times of the oil deposit pore volume;
(4) injecting a polymer composite foam flooding system into the water injection well, wherein the volume of the polymer composite foam flooding system is 0.03-0.05 time of the pore volume of the oil deposit;
(5) repeating the steps (2) to (4) until the total injection volume of the alternatively injected viscous oil viscosity-reducing oil displacement agent and the polymer composite foam oil displacement system is 0.3-0.5 times of the pore volume of the oil reservoir;
(6) and performing water flooding until the comprehensive water content is more than 95%.
The mass fraction of the thick oil viscosity-reducing oil displacement agent is 0.2-0.4%.
The polymer injection composite foam flooding system in the step (4) specifically comprises the following steps: preparing 4000-6000mg/L polymer mother liquor from the polymer, pumping the foaming agent into a liquid injection pipeline by using a liquid injection pump, mixing the foaming agent with the polymer mother liquor and sewage to prepare mixed solution containing 1500-2000mg/L polymer and 0.3-0.5wt% foaming agent, injecting foaming gas at the same time, wherein the gas-liquid ratio is (0.5-1):1, and mixing to form the polymer foam composite fluid.
The foaming gas is liquid nitrogen gasified gas, and the liquid nitrogen is directly used as a foaming gas source.
The polymer is polyacrylamide.
The technology is a novel method for improving the recovery ratio of the thick oil by alternately injecting a thick oil viscosity-reducing oil displacement agent, water and a polymer composite foam oil displacement system, wherein the thick oil viscosity-reducing oil displacement agent plays a role in stripping crude oil from the surface of oil reservoir rocks, reducing the viscosity of the crude oil and improving the fluidity, a polymer foam composite fluid formed by the polymer composite foam oil displacement system plays a role in increasing the swept, and the two modes are combined and cooperated to improve the recovery ratio of the thick oil under a non-heating condition.
The polyacrylamide polymer used in the invention is added into the foaming agent solution, so that the stability of a foaming system is increased, the adsorption of the foaming agent is reduced, the used foaming gas is liquid nitrogen gasified (or natural gas), the purity is high, the influence of nitrogen impurity (oxygen) on the composite system and the performance of crude oil is avoided, in addition, the liquid nitrogen is used as a foaming gas source to improve the foam quality and stability, and the formed polymer composite foam system plays a role in selective plugging and high profile control capability; the invention has the advantages that the recovery ratio of the heavy oil can be improved in a mode of not heating the stratum in the heavy oil reservoir, and the recoverable reserve of the oil field is increased.
Experiments prove that the oil displacement effect of the invention is to improve the recovery ratio of the heavy oil reservoir by more than 15%.
Drawings
FIG. 1 is a plot of recovery versus water for an indoor physical simulation test of the present invention.
Detailed Description
Fig. 1 shows the relationship between the comprehensive water content and the comprehensive recovery ratio in the experimental process and the change of the injection multiple in the simulation test process, and as can be seen from fig. 1, the oil displacement mode adopts the alternative oil displacement of the invention after water displacement to greatly improve the recovery ratio of the heavy oil reservoir.
The present invention is further illustrated by the following examples, which will enable those skilled in the art to better understand the technical solutions of the present invention.
Example 1: foam composite cold recovery method for improving recovery ratio of heavy oil reservoir
The method comprises the following steps:
(1) water is driven until the comprehensive water content is more than 95 percent;
(2) injecting a thick oil viscosity-reducing oil-displacing agent into the water injection well, wherein the volume of the thick oil viscosity-reducing oil-displacing agent is 0.04 times of the pore volume of the oil reservoir;
(3) the water flooding well injects water to recover water drive, and the water injection volume is 0.04 times of the pore volume of the oil reservoir;
(4) injecting a polymer composite foam flooding system into the water injection well, wherein the volume of the polymer composite foam flooding system is 0.04 times of the pore volume of the oil deposit;
(5) repeating the steps (2) to (4) until the total injection volume of the alternatively injected viscous oil viscosity-reducing oil displacement agent and the polymer composite foam oil displacement system is 0.3 times of the pore volume of the oil reservoir;
(6) and performing water flooding until the comprehensive water content is more than 95%.
The polymer injection composite foam flooding system in the step (4) specifically comprises the following steps: preparing polyacrylamide into 5000mg/L polymer mother liquor, pumping a foaming agent into a liquid injection pipeline by using a liquid injection pump, mixing the foaming agent with the polymer mother liquor and sewage to prepare a mixed solution containing 1800mg/L polymer and 0.5wt% of the foaming agent, and simultaneously injecting gasified liquid nitrogen with the gas-liquid ratio of 0.5:1 to form the polymer foam composite fluid by mixing.
Example 2: foam composite cold recovery method for improving recovery ratio of heavy oil reservoir
The method comprises the following steps:
(1) water is driven until the comprehensive water content is more than 95 percent;
(2) injecting a thick oil viscosity-reducing oil-displacing agent into the water injection well, wherein the volume of the thick oil viscosity-reducing oil-displacing agent is 0.05 times of the pore volume of the oil reservoir;
(3) the water flooding well injects water to recover water drive, and the water injection volume is 0.03 times of the pore volume of the oil reservoir;
(4) injecting a polymer composite foam flooding system into the water injection well, wherein the volume of the polymer composite foam flooding system is 0.05 times of the pore volume of the oil deposit;
(5) repeating the steps (2) to (4) until the total injection volume of the alternatively injected viscous oil viscosity-reducing oil displacement agent and the polymer composite foam oil displacement system is 0.5 times of the pore volume of the oil reservoir;
(6) and performing water flooding until the comprehensive water content is more than 95%.
The polymer injection composite foam flooding system in the step (4) specifically comprises the following steps: preparing 4000mg/L of polyacrylamide into a polymer mother liquor, pumping a foaming agent into a liquid injection pipeline by using a liquid injection pump, mixing the foaming agent with the polymer mother liquor and sewage to prepare a mixed solution containing 2000mg/L of polymer and 0.3wt% of the foaming agent, injecting gasified liquid nitrogen at the same time, and mixing the solution and the gasified liquid nitrogen according to the gas-liquid ratio of 1:1 to form the polymer foam composite fluid.
Example 3: foam composite cold recovery method for improving recovery ratio of heavy oil reservoir
The method comprises the following steps:
(1) water is driven until the comprehensive water content is more than 95 percent;
(2) injecting a thick oil viscosity-reducing oil-displacing agent into the water injection well, wherein the volume of the thick oil viscosity-reducing oil-displacing agent is 0.03 time of the pore volume of the oil reservoir;
(3) the water flooding well injects water to recover water drive, and the water injection volume is 0.05 times of the pore volume of the oil reservoir;
(4) injecting a polymer composite foam flooding system into the water injection well, wherein the volume of the polymer composite foam flooding system is 0.03 time of the pore volume of the oil deposit;
(5) repeating the steps (2) to (4) until the total injection volume of the alternatively injected viscous oil viscosity-reducing oil displacement agent and the polymer composite foam oil displacement system is 0.4 times of the pore volume of the oil reservoir;
(6) and performing water flooding until the comprehensive water content is more than 95%.
The polymer injection composite foam flooding system in the step (4) specifically comprises the following steps: preparing the polyacrylamide into 6000mg/L polymer mother liquor, pumping the foaming agent into a liquid injection pipeline by using an injection pump, mixing the foaming agent with the polymer mother liquor and sewage to prepare a mixed solution containing 1500mg/L polymer and 0.5wt% foaming agent, injecting gasified liquid nitrogen at the same time, and mixing the solution and the gasified liquid nitrogen to form the polymer foam composite fluid, wherein the gas-liquid ratio is 0.5: 1.
Test example 1: oil displacement effect simulation test
The test method comprises the following steps: comparative experiment: firstly, performing water flooding until the injection multiple is 0.77PV, the comprehensive water content is 100 percent, and the comprehensive recovery ratio is 18.1 percent; injecting 0.3PV thick oil viscosity reduction cold recovery agent, then subsequently driving water to 1.99PV, wherein the comprehensive water content is 100%, the comprehensive recovery ratio is 22.2%, and the comprehensive recovery ratio is improved by 4.1% compared with that before transfer injection;
taking example 1 as an example, a physical simulation test in a thickened oil production room is carried out, and when water flooding is carried out to the injection multiple of 0.77PV, the comprehensive water content is 100% and the comprehensive recovery ratio is 18.1%; injecting 0.3PV thick oil viscosity reduction cold recovery agent, then subsequently driving water to 1.99PV, wherein the comprehensive water content is 100%, the comprehensive recovery ratio is 22.2%, and the comprehensive recovery ratio is improved by 4.1% compared with that before transfer injection; and then alternately injecting a thickened oil viscosity-reducing oil displacement agent with the mass fraction of 0.3%, water and a polymer composite foam oil displacement system, wherein the injection multiple is 0.3PV, and finally, water is driven to the comprehensive water content of 100%, the comprehensive recovery ratio is 45.9%, and the comprehensive recovery ratio is improved by 23.7% compared with that before transfer injection.
Claims (1)
1. A foam composite cold recovery method for improving the recovery efficiency of a heavy oil reservoir is characterized in that a heavy oil viscosity-reducing oil displacement agent, water and a polymer composite foam oil displacement system are alternately injected into a water injection well and then water displacement is carried out;
the method comprises the following steps:
(1) water is driven until the comprehensive water content is more than 95 percent;
(2) injecting a thick oil viscosity-reducing oil-displacing agent into the water injection well, wherein the volume of the thick oil viscosity-reducing oil-displacing agent is 0.03-0.05 times of the pore volume of the oil reservoir;
(3) the water flooding well injects water to recover water drive, the water injection volume is 0.03-0.05 times of the oil deposit pore volume;
(4) injecting a polymer composite foam flooding system into the water injection well, wherein the volume of the polymer composite foam flooding system is 0.03-0.05 time of the pore volume of the oil deposit;
(5) repeating the steps (2) to (4) until the total injection volume of the alternatively injected viscous oil viscosity-reducing oil displacement agent and the polymer composite foam oil displacement system is 0.3-0.5 times of the pore volume of the oil reservoir;
(6) performing water flooding until the comprehensive water content is more than 95%;
the polymer composite foam flooding system specifically comprises: preparing 4000-6000mg/L polymer mother liquor from the polymer, pumping the foaming agent into a liquid injection pipeline by using a liquid injection pump, mixing the foaming agent with the polymer mother liquor and sewage to prepare mixed solution containing 1500-2000mg/L polymer and 0.3-0.5wt% foaming agent, and injecting foaming gas at the same time, wherein the gas-liquid ratio is (0.5-1):1, and mixing to form polymer foam composite fluid; the foaming gas is liquid nitrogen gasified gas, and the polymer is polyacrylamide.
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| CA3146893A1 (en) * | 2019-08-15 | 2021-02-18 | Pramod PATIL | Additive for enhanced oil recovery |
| 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 |
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| US4694906A (en) * | 1985-08-30 | 1987-09-22 | Union Oil Company Of California | Method for emplacement of a gelatinous foam in gas flooding enhanced recovery |
| US4813484A (en) * | 1987-12-28 | 1989-03-21 | Mobil Oil Corporation | Chemical blowing agents for improved sweep efficiency |
| WO1999051854A1 (en) * | 1998-04-06 | 1999-10-14 | Da Qing Petroleum Administration Bureau | A foam drive method |
| CN102061906B (en) * | 2010-12-09 | 2013-03-27 | 延长油田股份有限公司 | Air foam slug flow driving process for oil recovery of oil field |
| CN103306648B (en) * | 2013-06-28 | 2015-12-09 | 成都理工大学 | The method of viscous crude foam flooding |
| CN104265252B (en) * | 2014-08-19 | 2017-07-07 | 中国石油天然气股份有限公司 | Artificial foam oil displacement exploitation method for heavy oil reservoir |
| CN106801597A (en) * | 2015-11-26 | 2017-06-06 | 中国石油化工股份有限公司 | Heavy crude reservoir combined type flooding method and displacement composition |
| CN105909221B (en) * | 2016-04-21 | 2018-02-27 | 烟台智本知识产权运营管理有限公司 | A kind of method that heavy oil wells single well stimulation recovers the oil |
| CN107365575B (en) * | 2017-06-15 | 2019-10-18 | 中国石油化工股份有限公司 | A kind of viscosity reduction oil displacement agent and oil displacement system suitable for heavy crude reservoir |
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