CN113090233B - Heterogeneous reservoir CO simulation 2 Flooding, injection and production coupling experimental device and method - Google Patents
Heterogeneous reservoir CO simulation 2 Flooding, injection and production coupling experimental device and method Download PDFInfo
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- CN113090233B CN113090233B CN202110326573.3A CN202110326573A CN113090233B CN 113090233 B CN113090233 B CN 113090233B CN 202110326573 A CN202110326573 A CN 202110326573A CN 113090233 B CN113090233 B CN 113090233B
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- 238000004519 manufacturing process Methods 0.000 title claims abstract description 67
- 238000010168 coupling process Methods 0.000 title claims abstract description 58
- 238000002347 injection Methods 0.000 title claims abstract description 55
- 239000007924 injection Substances 0.000 title claims abstract description 55
- 230000008878 coupling Effects 0.000 title claims abstract description 53
- 238000005859 coupling reaction Methods 0.000 title claims abstract description 53
- 238000000034 method Methods 0.000 title claims abstract description 37
- 238000004088 simulation Methods 0.000 title claims description 13
- 239000011435 rock Substances 0.000 claims abstract description 69
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 58
- 238000006073 displacement reaction Methods 0.000 claims abstract description 50
- 238000002474 experimental method Methods 0.000 claims abstract description 41
- 230000008569 process Effects 0.000 claims abstract description 18
- 238000011084 recovery Methods 0.000 claims abstract description 15
- 230000008859 change Effects 0.000 claims abstract description 14
- 238000012360 testing method Methods 0.000 claims abstract description 11
- 230000032683 aging Effects 0.000 claims abstract description 5
- 230000000704 physical effect Effects 0.000 claims abstract description 5
- 229920006395 saturated elastomer Polymers 0.000 claims description 24
- 239000007788 liquid Substances 0.000 claims description 14
- 230000005465 channeling Effects 0.000 claims description 10
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 10
- 230000035699 permeability Effects 0.000 claims description 10
- 239000012153 distilled water Substances 0.000 claims description 8
- 238000012544 monitoring process Methods 0.000 claims description 5
- 238000002791 soaking Methods 0.000 claims description 5
- 239000000243 solution Substances 0.000 claims description 5
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical class [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 4
- 238000004364 calculation method Methods 0.000 claims description 4
- 238000001035 drying Methods 0.000 claims description 4
- 239000003350 kerosene Substances 0.000 claims description 4
- 238000000691 measurement method Methods 0.000 claims description 4
- 238000011049 filling Methods 0.000 claims description 3
- 238000002156 mixing Methods 0.000 claims description 3
- 238000009738 saturating Methods 0.000 claims description 3
- 239000003921 oil Substances 0.000 description 98
- 239000007789 gas Substances 0.000 description 59
- 238000005516 engineering process Methods 0.000 description 16
- 239000010779 crude oil Substances 0.000 description 11
- 238000011160 research Methods 0.000 description 8
- 238000011161 development Methods 0.000 description 7
- 230000018109 developmental process Effects 0.000 description 7
- 230000001965 increasing effect Effects 0.000 description 7
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 6
- 230000000694 effects Effects 0.000 description 6
- 239000010410 layer Substances 0.000 description 4
- 239000001569 carbon dioxide Substances 0.000 description 3
- 229910002092 carbon dioxide Inorganic materials 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000000605 extraction Methods 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- 238000005457 optimization Methods 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- 230000001360 synchronised effect Effects 0.000 description 2
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000005540 biological transmission Effects 0.000 description 1
- 229910002091 carbon monoxide Inorganic materials 0.000 description 1
- 239000000567 combustion gas Substances 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 238000003912 environmental pollution Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 239000011229 interlayer Substances 0.000 description 1
- 230000002427 irreversible effect Effects 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 230000000737 periodic effect Effects 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 238000012827 research and development Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 230000009919 sequestration Effects 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 239000002699 waste material Substances 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
- E21B43/164—Injecting CO2 or carbonated water
-
- 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
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
-
- 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
- E21B47/00—Survey of boreholes or wells
-
- 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
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
- Y02C20/00—Capture or disposal of greenhouse gases
- Y02C20/40—Capture or disposal of greenhouse gases of CO2
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
- Y02P90/70—Combining sequestration of CO2 and exploitation of hydrocarbons by injecting CO2 or carbonated water in oil wells
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
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- Chemical & Material Sciences (AREA)
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Abstract
The invention discloses a method for simulating heterogeneous reservoir CO 2 The experimental device comprises a displacement pump, an intermediate container, a rock core holder, a back pressure valve, a back pressure pump, a confining pressure pump and a measuring cylinder; the intermediate container comprises an intermediate container for containing the oil sample and a container for containing CO 2 The intermediate container of (1). The experimental method comprises the following steps: preparing an oil sample and a water sample for an experiment; testing the physical properties of the core foundation; establishing irreducible water saturation; keeping stratum conditions for simulating reservoir aging; CO 2 2 Testing an injection-production coupling experiment; measuring the pressure change of an injection end, the volume of the oil and gas to be displaced and the accumulated volume of the injected gas in the displacement process; and evaluating the capability of improving the recovery ratio of the heterogeneous reservoir by different injection-production coupling modes. The method can evaluate the capability of improving the recovery ratio of the heterogeneous reservoir by different injection-production coupling modes, and provides theoretical guidance for the application of the oil field and the mine site.
Description
Technical Field
The invention relates to the field of oil and gas field development engineering, in particular to a method for simulating heterogeneous reservoir CO 2 A flooding injection production coupling experimental device and a method.
Background
With the increasing demand of petroleum in China, it is proved that the petroleum and natural gas yield of the conventional oil reservoir cannot meet the increasing demand of national consumption, and the contradiction between supply and demand is increasingly prominent. Therefore, the rational and large-scale exploitation of unconventional oil reservoirs is an urgent problem to be solved in China, and plays an important role in the development of the petroleum industry in China.
Low permeability reservoir due to reservoir porositySmall, water flooding displacement is difficult to implement effectively, while chemical displacement easily causes irreversible damage to the original stratum and blocks the reservoir; if the depletion type oil reservoir development is adopted, if the energy is not supplemented in time, the elastic energy of the oil reservoir is depleted too fast, the recovery ratio is too low, and the great waste of underground crude oil resources is easily caused. Therefore, a new technology for improving the recovery ratio is urgently needed to be found to adapt to the characteristics of poor connectivity, strong Jamin effect, large starting pressure and the like of a low-permeability reservoir stratum. In view of this problem, CO is rapidly developed in recent years at home and abroad 2 Research and development and application of an oil displacement technology. The technology can meet the requirements of oil field development, solve the problem of carbon dioxide sequestration and reduce environmental pollution. After carbon dioxide is dissolved in water in the stratum, the viscosity of water can be increased, the migration performance is improved, and after carbon dioxide is dissolved in oil, the volume of crude oil is expanded, the viscosity is reduced, the oil-water interfacial tension is reduced, and the improvement of CO is facilitated 2 Sweep efficiency and wash oil efficiency. Foreign to CO 2 The research and application of the oil displacement technology begin earlier, and after decades of development, CO is 2 The flooding technology has evolved from an uncertain technology to a mature enhanced oil recovery technology. Meanwhile, foreign gas reserves are rich, and gas transmission pipeline systems are developed and are CO 2 The oil displacement provides sufficient air source guarantee. And domestic CO 2 The research of oil production technology is started later, but the field practice of each oil field shows that CO 2 The oil displacement technology has obvious oil increasing and production increasing effects although CO 2 The oil displacement technology has not become the leading technology applied in China, but can be predicted along with high-purity CO 2 Sequential discovery of gas reservoirs and increased scope of application, CO 2 The oil displacement technology can obtain a large development space.
However, with the increase of the gas injection age, the produced well gas channeling is serious and is characterized by high gas content and low oil content, and the influence of stratum heterogeneity on crude oil production is gradually highlighted. The high-permeability layer crude oil extraction degree is high, the high-permeability layer crude oil extraction degree becomes a main channel for oil and gas migration, the conventional synchronous gas injection degree is lower for residual oil in a low-permeability area, and most of the residual oil is enriched in the low-permeability layer. In order to use the residual oil in the low-permeability area in the heterogeneous stratum of the oil reservoir, an injection-production coupling technology is provided on the basis of the original conventional synchronous gas injection mode, the technology covers the adjustment methods of gas injection wells such as periodic gas injection and advanced gas injection, and an unstable pressure field is formed in the stratum, so that the oil and water in the oil reservoir can be redistributed, the wave range of injected gas is changed to enable the injected gas to reach the low-permeability area, and the crude oil recovery rate is improved. The injection-production coupling technology is an effective method for further improving the crude oil utilization capacity of the heterogeneous reservoir on the basis of the existing oil reservoir gas drive development, and has good application prospect.
The currently published research mainly focuses on the optimization design of injection and production process parameters on the actual oil reservoir conditions by adopting a numerical simulation means, and the main research aspects focus on the water injection coupling aspect, the gas injection coupling aspect has less research, and the experimental means is lacked to carry out CO (carbon monoxide) optimization on the interlayer heterogeneity of the low-permeability reservoir 2 And (4) evaluating the effect of improving the recovery ratio by the coupling of flooding, injection and production.
Disclosure of Invention
Based on the technical problem, the invention provides a method for simulating heterogeneous reservoir CO 2 A flooding injection production coupling experimental device and a method. The invention can simulate heterogeneous reservoir CO 2 And (3) a flooding injection-production coupling process is carried out, so that the capability of improving the recovery ratio of the heterogeneous reservoir by different injection-production coupling modes is determined, and theoretical guidance is provided for the application of the oil field and the mine field.
The technical solution adopted by the invention is as follows:
simulation heterogeneous reservoir CO 2 The injection-production coupling experimental device comprises a displacement pump, an intermediate container, a rock core holder, a back pressure valve, a back pressure pump, a confining pressure pump and a measuring cylinder;
the intermediate container comprises an intermediate container for containing the oil sample and a container for containing CO 2 The inlet end of the intermediate container for containing the oil sample is connected with the displacement pump through a pipeline No. 1, a two-way valve No. 1 is arranged on the pipeline No. 1, the outlet end of the intermediate container for containing the oil sample is connected with the main pipeline through a pipeline No. 2, and a two-way valve No. 2 is arranged on the pipeline No. 2;
contain CO 2 The inlet end of the intermediate container is connected with a displacement pump through a pipeline No. 4, and the pipeline No. 4 is provided withHas a two-way valve No. 4 for containing CO 2 The outlet end of the middle container is connected with a main pipeline through a pipeline No. 3, and a two-way valve No. 3 is arranged on the pipeline No. 3;
an injection valve and a four-way valve are arranged on the main pipeline, one port of the four-way valve is connected with a pressure gauge No. 1, and the other port of the four-way valve is connected with an emptying valve;
the core holder comprises a core holder No. 1 and a core holder No. 2, a main pipeline is connected with the inlet end of the core holder No. 1 through a pipeline No. 5, a two-way valve No. 5 is arranged on the pipeline No. 5, the main pipeline is connected with the inlet end of the core holder No. 2 through a pipeline No. 6, and a two-way valve No. 6 is arranged on the pipeline No. 6;
the back pressure valve comprises a back pressure valve No. 1 and a back pressure valve No. 2, the outlet end of the core holder No. 1 is connected with the back pressure valve No. 1 through a pipeline No. 7, a two-way valve No. 7 is arranged on the pipeline No. 7, the outlet end of the core holder No. 2 is connected with the back pressure valve No. 2 through a pipeline No. 8, and a two-way valve No. 8 is arranged on the pipeline No. 8;
the measuring cylinder comprises a measuring cylinder No. 1, a measuring cylinder No. 2, a measuring cylinder No. 3 and a measuring cylinder No. 4, the back pressure valve No. 1 is connected with the measuring cylinder No. 1 through a pipeline No. 9, the measuring cylinder No. 1 is connected with the measuring cylinder No. 3 through a pipeline No. 10, and the measuring cylinder No. 3 is inversely placed in the container No. 1; the back pressure valve No. 2 is connected with the measuring cylinder No. 2 through a pipeline No. 11, the measuring cylinder No. 2 is connected with the measuring cylinder No. 4 through a pipeline No. 12, and the measuring cylinder No. 4 is inversely placed in the container No. 2;
the measuring cylinder No. 1 and the measuring cylinder No. 2 are used for measuring the volume of discharged liquid, the tops of the measuring cylinder No. 1 and the measuring cylinder No. 2 are sealed, the measuring cylinder No. 3 and the measuring cylinder No. 4 are used for measuring the volume of discharged gas, and the container No. 1, the container No. 2, the measuring cylinder No. 3 and the measuring cylinder No. 4 are filled with liquid;
the number 1 of the core holder and the number 2 of the core holder are both connected with a confining pressure pump through a number 13 of a pipeline, and a number 2 of a pressure gauge is arranged on the number 13 of the pipeline;
no. 1 back-pressure valve and No. 2 back-pressure valve still all are connected with the back-pressure pump through No. 14 pipelines, are provided with the manometer No. 3 on No. 14 pipelines.
Heterogeneous reservoir CO simulation 2 The flooding injection-production coupling experimental method adopts the methodThe device comprises the following steps:
(1) Preparing an oil sample and a water sample for an experiment;
(2) Testing the physical properties of the core foundation;
(3) Establishing irreducible water saturation;
injecting a core of saturated water into the prepared oil sample, performing oil flooding until no water flows out of the outlet end of the core, and calculating the saturation of the bound water;
the irreducible water saturation calculation formula is as follows:
in the formula (1), L represents the length of the core in cm; h is the diameter of the core, cm; phi-core porosity,%; v An outlet Water quantity at outlet end, cm 3 ；
(4) Keeping stratum conditions for simulating reservoir aging;
(5)CO 2 injection-production coupling experiment test comprises:
(1) continuous CO injection at constant rate into parallel cores of saturated oil 2 Performing a gas-oil displacement experiment until no oil flows out, wherein the back pressure is constant in the process;
(2) respectively putting cores with different permeabilities into the core holder No. 1 and the core holder No. 2, wherein the core holder No. 1 or the core holder No. 2 holding a high-permeability core is called a high-permeability core channel, and the core holder No. 1 or the core holder No. 2 holding a low-permeability core is called a low-permeability core channel; after continuous gas drive and gas channeling, closing the high-permeability core channel and continuously injecting gas into the low-permeability core channel;
(3) performing injection-production coupling mode adjustment on the parallel cores displaced in the modes (1) and (2), wherein the injection-production coupling mode adjustment comprises adjustment of an injection end, adjustment of a production end and coupling between the two injection-production ends;
(6) Measuring the pressure change of an injection end, the volume of the oil and gas to be displaced and the accumulated volume of the injected gas in the displacement process;
(7) And evaluating the capability of improving the recovery ratio of the heterogeneous reservoir by different injection-production coupling modes.
Preferably, in step (1): the oil sample used in the experiment is live oil prepared by mixing methane and kerosene according to a gas-oil ratio and a viscosity value; distilled water was used as a water sample for the experiment.
Preferably, step (2) comprises: measuring the length, the diameter and the dry weight of the core; extracting and drying the natural rock core, and respectively measuring the permeability of the rock core by a gas measurement method; the core was saturated with distilled water and the core porosity was measured.
Preferably, during the experiment, the container No. 1, the container No. 2, the measuring cylinder No. 3 and the measuring cylinder No. 4 are all filled with saturated sodium carbonate solution.
Simulating heterogeneous reservoir CO as described above 2 The flooding injection-production coupling experimental method comprises the following specific processes:
firstly, respectively placing a core after saturated water in a core holder No. 1 and a core holder No. 2, simultaneously applying confining pressure to the core holder No. 1 and the core holder No. 2 by utilizing a confining pressure pump, and displaying the applied confining pressure by a pressure gauge No. 2;
respectively applying back pressure to a back pressure valve No. 1 and a back pressure valve No. 2 by using a back pressure pump, and reading the size of the back pressure by a pressure gauge No. 3;
putting the oil sample into an intermediate container for containing the oil sample, and adding CO 2 Pressurized and introduced into the container containing CO 2 The intermediate container of (4);
opening a two-way valve No. 1, a two-way valve No. 2, an injection valve, a two-way valve No. 5 and a two-way valve No. 7, closing a two-way valve No. 3, a two-way valve No. 4, a two-way valve No. 6 and a two-way valve No. 8, using a displacement pump to displace an oil sample in an intermediate container for containing the oil sample into a rock core at the inner side of a rock core holder No. 1, saturating the rock core with oil, simultaneously using a measuring cylinder No. 1 to measure the displaced water quantity, and using a measuring cylinder No. 3 to measure the volume of displaced gas;
when the core in the core holder No. 2 is subjected to saturated oil sample operation, the two-way valve No. 5 and the two-way valve No. 7 are closed, the two-way valve No. 6 and the two-way valve No. 8 are opened, an oil sample in a middle container for containing the oil sample is displaced by a displacement pump to enter the core in the core holder No. 2, saturated oil is carried out on the core, the displaced water quantity is measured by the measuring cylinder No. 2, and the volume of displaced gas is measured by the measuring cylinder No. 4.
Simulating heterogeneous reservoir CO as described above 2 The flooding injection-production coupling experimental method further comprises the following specific processes:
after the rock core is saturated with the oil sample, the two-way valve No. 1 and the two-way valve No. 2 are closed, the emptying valve is opened to completely discharge the oil sample inside the pipeline, and then the emptying valve is closed;
opening the two-way valve No. 3 and the two-way valve No. 4, and filling CO by using the displacement pump 2 CO in the intermediate vessel 2 Pressurizing, reading the pressure by a pressure gauge No. 1, and when the pressure is CO 2 When the pressure is the same as the pressure in the rock core, opening the two-way valve No. 5 and the two-way valve No. 6, performing continuous gas drive operation on the rock cores in the rock core holder No. 1 and the rock core holder No. 2, and simultaneously measuring the amount of liquid and gas displaced by the rock core in the rock core holder No. 1 by using the measuring cylinder No. 1 and the measuring cylinder No. 3 respectively; respectively measuring the amount of liquid and gas displaced by the rock core in the rock core holder No. 2 by using the measuring cylinder No. 2 and the measuring cylinder No. 4; in the displacement process, the pressure gauge No. 1 monitors the change of inlet pressure in real time;
after continuous gas drive and gas channeling, closing the high-permeability core passage, specifically closing the two-way valve No. 5 and the two-way valve No. 7, or closing the two-way valve No. 6 and the two-way valve No. 8, and continuously carrying out gas drive on the low-permeability core passage;
after the low-permeability core channel is subjected to gas channeling, gas injection, injection and production coupling operation is adopted, the two-way valve No. 7 and the two-way valve No. 8 are closed, and CO is injected into the core holder No. 1 and the core holder No. 2 2 Then, closing an injection valve to perform a soaking operation on the core holder, and monitoring the pressure change in the soaking process in real time by using a pressure gauge No. 1;
after the well is stewed, opening the two-way valve No. 7 and the two-way valve No. 8, and measuring the volume of the liquid and the gas which are extracted by using the measuring cylinder No. 1, the measuring cylinder No. 2, the measuring cylinder No. 3 and the measuring cylinder No. 4;
it is then determined whether to proceed with CO 2 Displacing, if CO continues to be carried out 2 The displacement opens the fill valve.
The beneficial technical effects of the invention are as follows:
the invention creatively designs indoor simulated heterogeneous reservoir CO 2 The invention can simulate the injection-production coupling process in the production process of a real mine field and evaluate the effect of improving the recovery ratio by an injection-production coupling mode under the heterogeneity of oil reservoir layers.
The invention has simple operation, accurate measurement and CO separation 2 The research of the injection and production coupling experiment has certain reference value, and fills the gap of the current research on the gas injection, injection and production coupling technology.
The method can evaluate the capability of improving the recovery ratio of the heterogeneous reservoir by different injection-production coupling modes, and provides theoretical guidance for the application of the oil field and the mine site.
Drawings
The invention is further described in the following detailed description with reference to the drawings in which:
FIG. 1 is a diagram of the simulation of heterogeneous reservoir CO according to the present invention 2 The structural principle schematic diagram of the flooding injection-production coupling experimental device;
FIG. 2 is a graph showing the variation of the core displacement efficiency in different ways in an application example of the invention;
FIG. 3 is a graph showing the variation of the produced gas-oil ratio in different ways in an application example of the present invention;
FIG. 4 is a graph showing the variation of inlet pressure in different modes in an application example of the present invention.
In the figure: 1. a displacement pump, 2, a two-way valve No. 1, 3, an intermediate container for containing oil samples, 4, a two-way valve No. 2, 5, a two-way valve No. 3, 6, CO 2 The middle container 7, the two-way valve No. 4, the injection valve 8, the pressure gauge No. 1, the pressure gauge 10, the four-way valve 11, the blow-down valve 12, the two-way valve No. 5, the two-way valve No. 13, the two-way valve No. 6, the confining pressure pump 14, the pressure gauge No. 15, the pressure gauge No. 2, the core holder No. 16, the core holder No. 1, the core holder No. 17, the back pressure pump 18, the pressure gauge No. 3, the two-way valve No. 7, the two-way valve No. 21, the two-way valve No. 8, the back pressure valve No. 22, the back pressure valve No. 1, the back pressure valve No. 23, the back pressure valve No. 2, the measuring cylinder No. 24, the measuring cylinder No. 1, the measuring cylinder No. 2, the measuring cylinder No. 3, the measuring cylinder No. 27, the measuring cylinder No. 4, the measuring cylinder No. 28, the container No. 1, the 29 and the container No. 2.
Detailed Description
As shown in figure 1, a method for simulating heterogeneous reservoir CO 2 The injection-production coupling experimental device comprises a displacement pump 1, an intermediate container, a rock core holder, a back pressure valve, a back pressure pump 18, a confining pressure pump 14 and a measuring cylinder. The intermediate container comprises an intermediate container 3 for containing oil samples and CO 2 The middle container 6, 3 entrance points of middle container 3 of splendid attire oil appearance pass through pipeline No. 1 and are connected with displacement pump 1, are provided with two-way valve No. 12 on pipeline No. 1, and the middle container exit end of splendid attire oil appearance passes through pipeline No. 2 and is connected with main pipeline, is provided with two-way valve No. 2 on pipeline No. 2 and 4. Contain CO 2 The inlet end of the intermediate container 6 is connected with the displacement pump 1 through a pipeline 4, a two-way valve 4 and a two-way valve 7 are arranged on the pipeline 4 and used for containing CO 2 The outlet end of the middle container is connected with a main pipeline through a pipeline No. 3, and a two-way valve No. 3 and a two-way valve No. 5 are arranged on the pipeline No. 3. The two-way valve No. 2 and the two-way valve No. 3 are simultaneously connected with the injection valve 8, the injection valve 8 and the four-way valve 10 are arranged on a main pipeline, the upper port of the four-way valve 10 is connected with the pressure gauge No. 1 and No. 9 and used for monitoring inlet pressure, and the lower port of the four-way valve 10 is connected with the emptying valve 11. The core holder includes 16 and 17 core holder No. 1, and the main line passes through 5 inlet connections of pipeline No. 1 with the core holder, is provided with 12 two-way valves on 5 pipeline No., and the main line passes through 6 inlet connections of pipeline No. 2 with the core holder, is provided with 13 two-way valves on 6 pipeline No. 6.
The back pressure valve includes back pressure valve No. 1 22 and back pressure valve No. 2 23, and the exit end of rock core holder No. 1 passes through No. 7 connection back pressure valves No. 1 of pipeline, is provided with No. 7 two-way valves 20 on No. 7 of pipeline. The outlet end of the core holder No. 2 is connected with a back pressure valve No. 2 through a pipeline No. 8, and a two-way valve No. 8 is arranged on the pipeline No. 8. The graduated flask includes graduated flask No. 1 No. 24, graduated flask No. 2 No. 25, graduated flask No. 3 26 and graduated flask No. 4 No. 27, and backpressure valve 1 No. is connected with graduated flask No. 1 through pipeline 9, and graduated flask No. 1 is connected with graduated flask No. 3 through pipeline 10, and the 3 number inverted putting of graduated flask in container No. 1 28. Back pressure valve 2 number is connected with graduated flask 2 number through pipeline 11 number, and graduated flask 2 number is connected with graduated flask 4 number through pipeline 12 number, and the 4 number inverted placement of graduated flask are in container No. 2 29. Measuring cylinder No. 1 and measuring cylinder No. 2 are used for measuring the liquid volume that drives out, and the top of measuring cylinder No. 1 and measuring cylinder No. 2 is all sealed, and measuring cylinder No. 3 and measuring cylinder No. 4 are used for measuring the gas volume of institute's combustion gas, all fill with saturated sodium carbonate solution in container No. 1, container No. 2, measuring cylinder No. 3 and measuring cylinder No. 4.
No. 1 and No. 2 core holders are connected with a confining pressure pump 14 through a pipeline 13, and a pressure gauge 2 or 15 is arranged on the pipeline 13 and used for monitoring confining pressure. No. 1 back-pressure valve and No. 2 back-pressure valves still all are connected with back-pressure pump 18 through No. 14 pipelines, are provided with No. 3 19 manometer on No. 14 pipelines for monitor back-pressure.
Heterogeneous reservoir CO simulation 2 The flooding injection production coupling experimental method adopts the device, and comprises the following steps:
(1) And preparing oil samples and water samples for experiments. The oil sample used in the experiment is a live oil sample prepared by mixing methane and kerosene according to a gas-oil ratio and a viscosity value; distilled water was used as a water sample for the experiment.
(2) Testing the physical properties of the core foundation: measuring the length, the diameter and the dry weight of the core; extracting and drying the natural rock core, and respectively measuring the permeability of the rock core by a gas measurement method; the core was saturated with distilled water and the core porosity was measured.
(3) Irreducible water saturation is established.
And injecting the core of the saturated water into the prepared oil sample, performing oil displacement on the oil sample with the displacement pressure difference of 5MPa until no water flows out of the outlet end of the core, and calculating the saturation of the bound water.
The irreducible water saturation calculation formula is as follows:
in the formula (1), L represents the core length in cm; h is the diameter of the core, cm; phi-core porosity,%; v An outlet Water quantity at outlet end, cm 3 。
(4) Formation conditions were maintained for 72h to simulate reservoir aging.
(5)CO 2 Injection-production coupling experiment test comprises:
(1) continuous injection at constant rate into parallel cores of saturated oilCO 2 And performing a gas-oil displacement experiment until no oil flows out after displacement, wherein the back pressure is constant in the process.
(2) Respectively putting cores with different permeabilities into the core holder No. 1 and the core holder No. 2, wherein the core holder No. 1 or the core holder No. 2 holding a high-permeability core is called a high-permeability core channel, and the core holder No. 1 or the core holder No. 2 holding a low-permeability core is called a low-permeability core channel; and after continuous gas drive gas channeling, closing the high-permeability core channel and continuously injecting gas into the low-permeability core channel.
(3) And (3) performing injection-production coupling mode adjustment on the parallel cores displaced in the modes (1) and (2), wherein the injection-production coupling mode adjustment comprises adjustment of an injection end, adjustment of a production end and coupling between the two injection-production ends.
(6) The injection end pressure change, the volume of displaced oil and gas, and the cumulative injected gas volume during the displacement were measured.
(7) And evaluating the capability of improving the recovery ratio of the heterogeneous reservoir by different injection-production coupling modes.
During the experiment, the container No. 1, the container No. 2, the measuring cylinder No. 3 and the measuring cylinder No. 4 are all filled with saturated sodium carbonate solution.
Simulating heterogeneous reservoir CO as described above 2 The flooding injection production coupling experimental method comprises the following specific processes:
the method comprises the steps of firstly respectively placing the core after saturated water in a core holder No. 1 and a core holder No. 2, simultaneously applying confining pressure to the core holder No. 1 and the core holder No. 2 by utilizing a confining pressure pump, and displaying the applied confining pressure by a pressure gauge No. 2.
And (3) applying back pressure to the back pressure valve No. 1 and the back pressure valve No. 2 by utilizing a back pressure pump respectively, and reading the back pressure by a pressure gauge No. 3.
Putting the oil sample into an intermediate container for containing the oil sample, and adding CO 2 Pressurized and introduced into the container for containing CO 2 The intermediate container of (1).
Opening two-way valve No. 1, two-way valve No. 2, the injection valve, two-way valve No. 5 and two-way valve No. 7, closing two-way valve No. 3, two-way valve No. 4, two-way valve No. 6 and two-way valve No. 8, utilizing the displacement pump to displace the oil sample in the middle container for containing the oil sample into the rock core at the inner side of rock core holder No. 1, carrying out saturated oil on the rock core, utilizing measuring cylinder No. 1 to measure the displaced water quantity simultaneously, and utilizing measuring cylinder No. 3 to measure the volume of the displaced gas.
When the saturated oil sample operation is carried out on the rock core in the rock core holder No. 2, the two-way valve No. 5 and the two-way valve No. 7 are closed, the two-way valve No. 6 and the two-way valve No. 8 are opened, the oil sample in the middle container for containing the oil sample is driven by the displacement pump to enter the rock core in the rock core holder No. 2, the saturated oil is carried out on the rock core, meanwhile, the water volume displaced by the measuring cylinder No. 2 is used for measuring, and the volume of the gas displaced by the measuring cylinder No. 4 is used for measuring.
Simulating heterogeneous reservoir CO as described above 2 The flooding injection production coupling experimental method further comprises the following specific processes:
and after the rock core is saturated with the oil sample, closing the two-way valve No. 1 and the two-way valve No. 2, opening the emptying valve to completely discharge the oil sample in the pipeline, and then closing the emptying valve.
Opening the two-way valve No. 3 and the two-way valve No. 4, and filling CO by using the displacement pump 2 CO in the intermediate vessel 2 Pressurizing, reading the pressure by a pressure gauge No. 1, and when the pressure is CO 2 When the pressure is the same as the pressure in the rock core, opening the two-way valve No. 5 and the two-way valve No. 6, performing continuous gas drive operation on the rock cores in the rock core holder No. 1 and the rock core holder No. 2, and simultaneously measuring the amount of liquid and gas displaced by the rock core in the rock core holder No. 1 by using the measuring cylinder No. 1 and the measuring cylinder No. 3 respectively; respectively measuring the amount of liquid and gas displaced by the rock core in the rock core holder No. 2 by using the measuring cylinder No. 2 and the measuring cylinder No. 4; in the displacement process, the pressure gauge No. 1 monitors the change of the inlet pressure in real time.
And after the gas channeling is continuously driven, closing the high-permeability core passage, specifically closing the two-way valve No. 5 and the two-way valve No. 7, or closing the two-way valve No. 6 and the two-way valve No. 8, and continuously driving the low-permeability core passage by gas.
After the low-permeability core channel is subjected to gas channeling, gas injection, injection and production coupling operation is adopted, the two-way valve No. 7 and the two-way valve No. 8 are closed, and CO is injected into the core holder No. 1 and the core holder No. 2 2 Then, closing the injection valve to perform well stewing operation on the rock core holderAnd the pressure gauge No. 1 monitors the pressure change in the soaking process in real time.
And after the well is stewed, opening the two-way valve No. 7 and the two-way valve No. 8, and measuring the volume of the liquid and the gas which are extracted by using the measuring cylinder No. 1, the measuring cylinder No. 2, the measuring cylinder No. 3 and the measuring cylinder No. 4.
It is then determined whether to proceed with CO 2 Displacing, if CO continues 2 The displacement opens the fill valve.
The invention is further illustrated by the following specific application examples:
the application example utilizes the actual geological core of a certain oil field in China to evaluate CO 2 And (4) evaluating the effect of improving the recovery ratio and the injection capability by the coupling of flooding, injection and production. The experimental procedure was as follows:
(1) Preparing oil samples and water samples for experiments: the crude oil used in the experiment is mixed with methane and kerosene to prepare an oil sample according to the gas-oil ratio and the viscosity value, and the basic characteristic parameters of the crude oil are as follows: the saturation pressure is 10.18MPa, the volume coefficient of crude oil is 1.144, and the original gas-oil ratio is 37.6m 3 /m 3 The crude oil density is 791.4kg/m 3 The viscosity was 2.46 mPas, and distilled water was used as a water sample.
(2) Testing the physical properties of the core foundation: the core length, diameter, dry weight were measured. And (3) extracting and drying the natural rock core, respectively measuring the permeability of a plurality of rock cores by using a gas measurement method, saturating distilled water with a rock core model, and measuring the porosity of the rock core.
(3) Establishing irreducible water saturation: and (2) placing the core (1) after being saturated with water in a core holder No. 1 and the core (2) in a core holder No. 2. And applying confining pressure to the core holder No. 1 and the core holder No. 2 by using a confining pressure pump, wherein the confining pressure value is 25MPa, and the confining pressure value is read by a pressure gauge No. 2. And applying back pressure to the back pressure valve No. 1 and the back pressure valve No. 2 by using a back pressure pump 18, wherein the back pressure value is 13MPa and is read by a pressure gauge No. 3. And opening a two-way valve No. 1, a two-way valve No. 2, an injection valve, a two-way valve No. 5, a two-way valve No. 6, a two-way valve No. 7 and a two-way valve No. 8, and displacing the oil sample in the middle container for containing the oil sample into the rock core by using a displacement pump to drive water by the oil until no water flows out of the outlet end of the rock core, so as to calculate the saturation of the bound water.
The irreducible water saturation calculation formula is as follows:
in the formula: l is the length of the core, cm; h is the diameter of the core, cm; phi-core porosity,%; pi-circumference ratio; v An outlet Water quantity at outlet end, cm 3 。
The basic physical parameters of the actual geological core measured are shown in table 1:
TABLE 1
(4) Formation conditions were maintained for 72h to simulate reservoir aging.
(5)CO 2 Injection-production coupling experiment test
The first method is as follows: and (3) closing the two-way valve No. 1, the two-way valve No. 2, the two-way valve No. 5 and the two-way valve No. 6, opening the two-way valve No. 3, the two-way valve No. 4 and the vent valve, discharging the oil sample in the pipeline, and then closing the vent valve. Opening two-way valve No. 5 and two-way valve No. 6, and continuously injecting CO into rock core in parallel with saturated oil at the speed of 0.01ml/min 2 And carrying out continuous gas drive experiments until no oil flows out, measuring the oil mass displaced by the two rock cores by using a measuring cylinder No. 1 and a measuring cylinder No. 2, measuring the gas output of the two rock cores by using a measuring cylinder No. 3 and a measuring cylinder No. 4, and reading out the inlet pressure change by using a pressure gauge No. 1. The displacement efficiency in this manner is shown in fig. 2, the production gas-oil ratio variation is shown in fig. 3, and the injection pressure variation is shown in fig. 4.
The second method comprises the following steps: on the basis of the first mode, the two-way valve No. 6 is closed, the gas is continuously injected into the core No. 1, the displaced oil sample is measured by using the measuring cylinder No. 1, the gas outlet amount is measured by using the measuring cylinder No. 3, and the change of the inlet pressure is read by using the pressure gauge No. 1. The displacement efficiency in this manner is shown in fig. 2, the production gas-oil ratio variation is shown in fig. 3, and the injection pressure variation is shown in fig. 4.
The third method comprises the following steps: opening twoAnd the number 6 of the through valve, the number 7 of the two-way valve and the number 8 of the two-way valve are closed, and 0.5PVCO is injected into the parallel core after the mode one and the mode two are displaced at a constant speed of 0.01ml/min 2 And then opening the two-way valve No. 7 and the two-way valve No. 8, continuously displacing the inlet end at the speed of 0.01ml/min, metering the oil displacement of the two rock cores by the measuring cylinder No. 1 and the measuring cylinder No. 2, metering the gas discharge by the measuring cylinder No. 3 and the measuring cylinder No. 4, and monitoring the inlet pressure change by the pressure gauge No. 1. The displacement efficiency in this manner is shown in fig. 2, the production gas-oil ratio variation is shown in fig. 3, and the injection pressure variation is shown in fig. 4.
From the above experimental tests, it can be known that the experimental method and experimental apparatus designed by the present invention can accurately evaluate the change of the effect of increasing the recovery ratio and the injection capability after the injection-production coupling method is adopted for adjustment under the heterogeneous reservoir, besides the injection-production coupling method described in this embodiment, the technicians in this field can also adopt other injection-production coupling methods for combination to CO 2 The research of the flooding, injection and production coupling experiment has certain reference value.
Claims (6)
1. Heterogeneous reservoir CO simulation 2 The flooding injection-production coupling experiment method adopts simulation of heterogeneous reservoir CO 2 The device comprises a displacement pump, an intermediate container, a rock core holder, a back pressure valve, a back pressure pump, a confining pressure pump and a measuring cylinder;
the intermediate container comprises an intermediate container for containing the oil sample and a container for containing CO 2 The inlet end of the intermediate container for containing the oil sample is connected with the displacement pump through a pipeline No. 1, a two-way valve No. 1 is arranged on the pipeline No. 1, the outlet end of the intermediate container for containing the oil sample is connected with the main pipeline through a pipeline No. 2, and a two-way valve No. 2 is arranged on the pipeline No. 2;
contain CO 2 The inlet end of the intermediate container is connected with the displacement pump through a pipeline No. 4, a two-way valve No. 4 is arranged on the pipeline No. 4 and is used for containing CO 2 The outlet end of the middle container is connected with a main pipeline through a pipeline No. 3, and a two-way valve No. 3 is arranged on the pipeline No. 3;
an injection valve and a four-way valve are arranged on the main pipeline, one port of the four-way valve is connected with a pressure gauge No. 1, and the other port of the four-way valve is connected with an emptying valve;
the core holder comprises a core holder No. 1 and a core holder No. 2, a main pipeline is connected with the inlet end of the core holder No. 1 through a pipeline No. 5, a two-way valve No. 5 is arranged on the pipeline No. 5, the main pipeline is connected with the inlet end of the core holder No. 2 through a pipeline No. 6, and a two-way valve No. 6 is arranged on the pipeline No. 6;
the back pressure valve comprises a back pressure valve No. 1 and a back pressure valve No. 2, the outlet end of the core holder No. 1 is connected with the back pressure valve No. 1 through a pipeline No. 7, a two-way valve No. 7 is arranged on the pipeline No. 7, the outlet end of the core holder No. 2 is connected with the back pressure valve No. 2 through a pipeline No. 8, and a two-way valve No. 8 is arranged on the pipeline No. 8;
the measuring cylinder comprises a measuring cylinder No. 1, a measuring cylinder No. 2, a measuring cylinder No. 3 and a measuring cylinder No. 4, the back pressure valve No. 1 is connected with the measuring cylinder No. 1 through a pipeline No. 9, the measuring cylinder No. 1 is connected with the measuring cylinder No. 3 through a pipeline No. 10, and the measuring cylinder No. 3 is inversely placed in the container No. 1; the back pressure valve No. 2 is connected with the measuring cylinder No. 2 through a pipeline No. 11, the measuring cylinder No. 2 is connected with the measuring cylinder No. 4 through a pipeline No. 12, and the measuring cylinder No. 4 is inversely placed in the container No. 2;
the measuring cylinder No. 1 and the measuring cylinder No. 2 are used for measuring the volume of discharged liquid, the tops of the measuring cylinder No. 1 and the measuring cylinder No. 2 are sealed, the measuring cylinder No. 3 and the measuring cylinder No. 4 are used for measuring the volume of discharged gas, and the container No. 1, the container No. 2, the measuring cylinder No. 3 and the measuring cylinder No. 4 are filled with liquid;
the number 1 of the core holder and the number 2 of the core holder are both connected with a confining pressure pump through a number 13 of a pipeline, and a number 2 of a pressure gauge is arranged on the number 13 of the pipeline;
the back pressure valve No. 1 and the back pressure valve No. 2 are both connected with a back pressure pump through a pipeline No. 14, and a pressure gauge No. 3 is arranged on the pipeline No. 14; the method is characterized by comprising the following steps:
(1) Preparing an oil sample and a water sample for an experiment;
(2) Testing the basic physical properties of the rock core;
(3) Establishing irreducible water saturation;
injecting a core of saturated water into the prepared oil sample, performing oil flooding until no water flows out of the outlet end of the core, and calculating the saturation of the bound water;
the irreducible water saturation calculation formula is as follows:
in the formula (1), L represents the length of the core in cm; h is the diameter of the core, cm; phi-core porosity,%; v An outlet Water quantity at outlet end, cm 3 ；
(4) Keeping stratum conditions for simulating reservoir aging;
(5)CO 2 injection-production coupling experiment test comprises:
(1) continuous CO injection into parallel cores of saturated oil at constant rate 2 Performing a gas-oil displacement experiment until no oil flows out, wherein the back pressure is constant in the process;
(2) respectively placing cores with different permeabilities in the core holder No. 1 and the core holder No. 2, wherein the core holder No. 1 or the core holder No. 2 holding a core with high permeability is called a high-permeability core channel, and the core holder No. 1 or the core holder No. 2 holding a core with low permeability is called a low-permeability core channel; after continuous gas drive gas channeling, closing the high-permeability core channel and continuously injecting gas into the low-permeability core channel;
(3) performing injection-production coupling mode adjustment on the parallel cores displaced in the modes (1) and (2), wherein the injection-production coupling mode adjustment comprises adjustment of an injection end, adjustment of a production end and coupling between the two injection-production ends;
(6) Measuring the pressure change of an injection end, the volume of the oil and gas to be expelled and the accumulated volume of the injected gas in the displacement process;
(7) And evaluating the capability of improving the recovery ratio of the heterogeneous reservoir by different injection-production coupling modes.
2. The method for simulating heterogeneous reservoir CO according to claim 1 2 The flooding injection-production coupling experimental method is characterized in that in the step (1): the oil sample used in the experiment is prepared by mixing methane and kerosene according to gas-oil ratio and viscosity valueAn oil; distilled water was used as a water sample for the experiment.
3. Simulation heterogeneous reservoir CO according to claim 1 2 The flooding injection-production coupling experimental method is characterized in that the step (2) comprises the following steps: measuring the length, the diameter and the dry weight of the core; extracting and drying the natural rock core, and respectively measuring the permeability of the rock core by a gas measurement method; the core was saturated with distilled water and the core porosity was measured.
4. Simulation heterogeneous reservoir CO according to claim 1 2 The flooding injection-production coupling experimental method is characterized by comprising the following steps: during the experiment, the container No. 1, the container No. 2, the measuring cylinder No. 3 and the measuring cylinder No. 4 are all filled with saturated sodium carbonate solution.
5. Simulation heterogeneous reservoir CO according to claim 1 2 The flooding injection-production coupling experimental method is characterized by comprising the following specific processes:
firstly, respectively placing a core after saturated water in a core holder No. 1 and a core holder No. 2, simultaneously applying confining pressure to the core holder No. 1 and the core holder No. 2 by utilizing a confining pressure pump, and displaying the applied confining pressure by a pressure gauge No. 2;
respectively applying back pressure to a back pressure valve No. 1 and a back pressure valve No. 2 by using a back pressure pump, and reading the size of the back pressure by a pressure gauge No. 3;
putting the oil sample into an intermediate container for containing the oil sample, and adding CO 2 Pressurized and introduced into the container for containing CO 2 The intermediate container of (4);
opening a two-way valve No. 1, a two-way valve No. 2, an injection valve, a two-way valve No. 5 and a two-way valve No. 7, closing a two-way valve No. 3, a two-way valve No. 4, a two-way valve No. 6 and a two-way valve No. 8, using a displacement pump to displace an oil sample in an intermediate container for containing the oil sample into a rock core at the inner side of a rock core holder No. 1, saturating the rock core with oil, simultaneously using a measuring cylinder No. 1 to measure the displaced water quantity, and using a measuring cylinder No. 3 to measure the volume of displaced gas;
when the saturated oil sample operation is carried out on the rock core in the rock core holder No. 2, the two-way valve No. 5 and the two-way valve No. 7 are closed, the two-way valve No. 6 and the two-way valve No. 8 are opened, the oil sample in the middle container for containing the oil sample is driven by the displacement pump to enter the rock core in the rock core holder No. 2, the saturated oil is carried out on the rock core, meanwhile, the water volume displaced by the measuring cylinder No. 2 is used for measuring, and the volume of the gas displaced by the measuring cylinder No. 4 is used for measuring.
6. Simulation heterogeneous reservoir CO according to claim 1 2 The flooding injection-production coupling experimental method is characterized by further comprising the following specific processes:
after the rock core is saturated with the oil sample, the two-way valve No. 1 and the two-way valve No. 2 are closed, the emptying valve is opened to completely discharge the oil sample inside the pipeline, and then the emptying valve is closed;
opening the two-way valve No. 3 and the two-way valve No. 4, and filling CO by using the displacement pump 2 CO in the intermediate vessel 2 Pressurizing, reading the pressure by a pressure gauge No. 1, and when the pressure is CO 2 When the pressure is the same as the pressure in the rock core, opening the two-way valve No. 5 and the two-way valve No. 6, performing continuous gas drive operation on the rock cores in the rock core holder No. 1 and the rock core holder No. 2, and simultaneously measuring the amount of liquid and gas displaced by the rock core in the rock core holder No. 1 by using the measuring cylinder No. 1 and the measuring cylinder No. 3 respectively; respectively measuring the amount of liquid and gas displaced by the rock core in the rock core holder No. 2 by using the measuring cylinder No. 2 and the measuring cylinder No. 4; in the displacement process, the pressure gauge No. 1 monitors the change of inlet pressure in real time;
after the gas channeling is continuously driven by gas, closing the high-permeability core channel, specifically closing the two-way valve No. 5 and the two-way valve No. 7, or closing the two-way valve No. 6 and the two-way valve No. 8, and continuously driving the low-permeability core channel by gas;
after the low-permeability core channel is subjected to gas channeling, gas injection, injection and production coupling operation is adopted, the two-way valve No. 7 and the two-way valve No. 8 are closed, and CO is injected into the core holder No. 1 and the core holder No. 2 2 Then, closing the injection valve to perform soaking operation on the core holder, and monitoring pressure change in the soaking process in real time by using a pressure gauge No. 1;
after the well is stewed, opening the two-way valve No. 7 and the two-way valve No. 8, and measuring the volume of the liquid and the gas which are extracted by using the measuring cylinder No. 1, the measuring cylinder No. 2, the measuring cylinder No. 3 and the measuring cylinder No. 4;
it is then determined whether to proceed with CO 2 Displacing, if CO continues to be carried out 2 The displacement opens the fill valve.
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