A method and system for determining relative permeability considering CO2-crude oil interaction

Abstract

The application discloses a method and system for determining relative permeability considering CO2-oil interaction, and the system comprises: a first configuration device, a first determination device, a second determination device and a first displacement device; the first configuration device is used for obtaining formation gas live oil; the first determination device is used for obtaining live oil viscosity based on the formation gas live oil; the second determination device is used for measuring CO2 solubility of the gas live oil and CO2 solubility of formation water; and the first displacement device is used for obtaining relative permeability considering CO2-oil interaction based on the live oil viscosity, the CO2 solubility of the gas live oil and the CO2 solubility of the formation water. The application fully considers the dissolution and diffusion interaction between CO2 and gas-containing oil under real reservoir conditions and the dissolution and diffusion action of CO2 in the water phase, and improves the accuracy of the relative permeability test of the CO2-oil system under reservoir conditions.

Description

Technical Field

[0001] This invention belongs to the field of relative permeability measurement, and particularly relates to a method and system for relative permeability measurement that takes into account the interaction between CO2 and crude oil. Background Technology

[0002] In recent years, with the depletion of medium- and high-permeability oil and gas resources, unconventional oil reservoirs have accounted for nearly 40% of the world's crude oil supply. However, the primary recovery rate of unconventional oil reservoirs is only 1-2%. How to effectively develop low-permeability, tight oil and other resources has become a major challenge. Compared with conventional oil reservoirs, unconventional oil reservoirs have poor pore connectivity, and strong pore size effects and stress sensitivity result in a large amount of crude oil remaining in the reservoir, making it urgent to explore feasible enhanced oil recovery technologies.

[0003] CO2 injection offers advantages such as dissolution, expansion, viscosity reduction, and component mass transfer, achieving the dual goals of enhanced oil recovery and greenhouse gas storage, resulting in significant economic and social benefits. However, in real oil reservoirs, fluids such as oil, gas, and water are often present. The CO2 injection process in actual reservoirs involves complex three-phase flow processes involving oil, gas, and water. Due to the differences in their physical properties, these three phases interfere with each other during flow within the porous reservoir medium, making it difficult to quantify the flow characteristics of fluids under reservoir conditions. Currently, relative permeability curves are an important tool for accurately characterizing the fluid permeability of oil reservoirs. However, most current relative permeability curve experiments use degassed crude oil or aviation kerosene as simulated oil samples, which significantly deviate from the actual reservoir fluid conditions. Furthermore, existing experimental methods for relative permeability curves neglect the complex dissolution and diffusion interactions between CO2 and gaseous crude oil, leading to significant errors in the relative permeability curves obtained under actual reservoir conditions.

[0004] Therefore, there is an urgent need for a method and system for determining relative permeability that takes into account the interaction between CO2 and crude oil, in order to address the shortcomings of existing technologies. Summary of the Invention

[0005] The purpose of this invention is to propose a method and system for determining relative permeability that takes into account the interaction between CO2 and crude oil, so as to improve the accuracy of relative permeability testing of CO2-crude oil systems under reservoir conditions.

[0006] On the one hand, to achieve the above objectives, the present invention provides a relative permeability measurement system that takes into account the interaction between CO2 and crude oil, comprising:

[0007] A first configuration device, a first measuring device, a second measuring device, and a first displacement device;

[0008] The first configuration device is used to obtain gas-bearing active oil from the formation;

[0009] The first measuring device is used to obtain the viscosity of the active oil based on the gas-bearing active oil in the formation;

[0010] The second measuring device is used to measure the CO2 solubility in gas-bearing active oil and the CO2 solubility in formation water;

[0011] The first displacement device is used to obtain the relative permeability taking into account the interaction between CO2 and crude oil, based on the viscosity of the live oil, the CO2 solubility of the gas-bearing live oil, and the CO2 solubility of the formation water.

[0012] According to the relative permeability measurement system considering CO2-crude oil interaction provided by the present invention, the first configuration device includes a first injection pump, a heater, a live oil preparation container, and a live oil temporary storage container.

[0013] The first injection pump, the heater, the live oil preparation container and the live oil temporary storage container are connected in sequence by pipelines, and a plurality of first valve groups are provided in the pipelines, wherein the plurality of first valve groups include a first valve, a second valve and a third valve;

[0014] The first valve is located between the first injection pump and the heater, the second valve is located between the live oil preparation container and the live oil storage container, and the third valve is located at the bottom of the live oil storage container at a certain distance.

[0015] The live oil preparation container is equipped with a heater at the top to control the temperature of the first preparation device, and rotators are installed on both sides of the live oil preparation container to control its rotation.

[0016] According to the relative permeability measurement system considering CO2-crude oil interaction provided by the present invention, the first measuring device includes a second injection pump, the live oil temporary storage container, a first pressure monitoring device, a high-temperature and high-pressure reactor, and a high-precision live oil viscometer.

[0017] The second injection pump, the live oil temporary storage container, the first pressure monitoring device, the high-temperature and high-pressure reactor, and the high-precision live oil viscometer are connected in sequence through the pipeline, and a plurality of second valve groups are provided in the pipeline, wherein the plurality of second valve groups include a fourth valve, a fifth valve, and a sixth valve;

[0018] The fourth valve is located between the second injection pump and the live oil temporary storage container, the fifth valve is located between the live oil temporary storage container and the first pressure monitoring device, and the sixth valve is located between the high-temperature and high-pressure reactor and the high-precision live oil viscometer.

[0019] According to the relative permeability measurement system considering CO2-crude oil interaction provided by the present invention, the second measuring device includes a third injection pump, a first intermediate container, a second pressure monitoring device, and a second intermediate container.

[0020] The third injection pump, the first intermediate container, the second pressure monitoring device, and the second intermediate container are connected in sequence through the pipeline, and a plurality of third valve groups are provided in the pipeline, wherein the plurality of third valve groups include a seventh valve, an eighth valve, and a ninth valve;

[0021] The seventh valve is located between the third injection pump and the first intermediate container, the eighth valve is located between the first intermediate container and the second pressure monitoring device, and the ninth valve is located at the bottom of the second intermediate container at a certain distance.

[0022] According to the relative permeability measurement system considering CO2-crude oil interaction provided by the present invention, the first displacement device includes a constant temperature chamber, which is equipped with a fourth injection pump, several intermediate containers, a six-way valve, a confining pressure pump, a core holder, a back pressure valve, a fifth injection pump, a temperature sensor, a pressure sensor, and a control subsystem. The control subsystem is connected to a host computer, wherein the host computer is a computer system.

[0023] The fourth injection pump, several intermediate containers, the six-way valve, the core clamp, and the back pressure valve are connected in sequence through the pipeline. Several intermediate containers are connected in parallel through the pipeline, and the fourth injection pump and each intermediate container are equipped with a valve.

[0024] The core holder has a core holder inlet and a core holder outlet at both ends, and a confining pressure fluid inlet at the top. The confining pressure fluid inlet is connected to the fourteenth valve and the confining pressure pump in sequence through the pipeline.

[0025] The core holder is equipped with a thirteenth valve and a fifteenth valve at both ends. The thirteenth valve, the pressure sensor, and the fifteenth valve are connected in sequence through the pipeline, and the pressure sensor and the core holder are connected in parallel through the pipeline.

[0026] The pressure sensor is connected to the control subsystem and the host computer in sequence through the pipeline, and the back pressure valve is connected to the fifth injection pump through the pipeline.

[0027] On the other hand, to achieve the above objectives, the present invention provides a method for determining relative permeability considering the interaction between CO2 and crude oil, comprising the following steps:

[0028] The first configuration device was used to obtain gas-bearing active oil from the formation.

[0029] Based on the gas-bearing active oil in the formation, the viscosity of the active oil is obtained using a first measuring device;

[0030] The second measuring device was used to obtain the CO2 solubility in gas-bearing active oil and the CO2 solubility in formation water;

[0031] Based on the viscosity of the active oil, the CO2 solubility of the gas-bearing active oil, and the CO2 solubility of the formation water, the relative permeability considering the interaction between CO2 and crude oil is obtained using a first displacement device. The relative permeability considering the interaction between CO2 and crude oil includes the relative permeability of the gas-bearing active oil in the core and the relative permeability of CO2.

[0032] According to the relative permeability determination method considering CO2-crude oil interaction provided by the present invention, obtaining gas-bearing active oil in the formation using the first configuration device includes:

[0033] Heat the first configuration device to the reservoir temperature;

[0034] Based on the reservoir temperature, degassed dead oil and dissolved gas are injected into the first configuration device to obtain gas-bearing active oil from the formation.

[0035] According to the relative permeability determination method considering CO2-crude oil interaction provided by the present invention, based on the gas-bearing active oil in the formation, the viscosity of the active oil is obtained using the first measuring device, including:

[0036] The gas-bearing active oil in the formation is injected into the first measuring device, and the reservoir pressure and reservoir temperature of the first measuring device are maintained.

[0037] Based on the reservoir pressure and reservoir temperature, the viscosity of the live oil is obtained until the synergistic effect of CO2 dissolution and diffusion in the crude oil ends.

[0038] According to the relative permeability determination method considering CO2-crude oil interaction provided by the present invention, obtaining the CO2 solubility of the gas-bearing active oil and the CO2 solubility of the formation water using the second measuring device includes:

[0039] Obtain gas-bearing active oil and formation water from the formation;

[0040] Pure CO2 and the gas-bearing active oil in the formation are injected into the second measuring device, and the reservoir pressure and reservoir temperature are maintained in the second measuring device. After a target time, the first internal pressure is obtained, and then the CO2 solubility of the gas-bearing active oil is obtained.

[0041] The pure CO2 and the formation water are injected into the second measuring device, and the reservoir pressure and reservoir temperature are maintained in the second measuring device. After the target time, the second internal pressure is obtained, and then the CO2 solubility in the formation water is obtained.

[0042] According to the relative permeability determination method considering CO2-crude oil interaction provided by the present invention, based on the viscosity of the active oil, the CO2 solubility of the gas-bearing active oil, and the CO2 solubility of the formation water, the relative permeability considering CO2-crude oil interaction is obtained using a first displacement device, including:

[0043] The core pore volume is calculated by analyzing the core porosity, length, and cross-sectional area, and then the nitrogen and CO2 viscosity at the reservoir pressure and temperature are retrieved.

[0044] The core is placed in the first displacement device, and the first displacement device is evacuated to reach the target temperature, and the back pressure valve of the first displacement device reaches the first target pressure, and the confining pressure of the first displacement device reaches the second target pressure, thereby obtaining the target back pressure and the target flow pressure.

[0045] The volume of nitrogen flowing into the first displacement device is obtained by using nitrogen and the first displacement device, and the absolute permeability of the core is obtained based on the target flow pressure, the target back pressure, the nitrogen viscosity, the length and cross-sectional area of ​​the core.

[0046] Binding formation water is obtained, and saturated gas-bearing active oil is obtained through the first displacement device. Then, the volume of saturated formation water, the volume of saturated gas-bearing active oil, and the volume of formation water at the producing end are recorded.

[0047] The first displacement device was used to conduct a CO2 displacement experiment on gas-bearing active oil to obtain the volume of gas-bearing active oil at the production end, the amount of CO2 injected and the amount of CO2 produced, as well as the pressure at the injection end and the pressure at the production end in the core holder.

[0048] The volume of gas-bearing active oil in the core is calculated by using the volume of gas-bearing active oil at the producing end and the volume of saturated gas-bearing active oil. The effective permeability of the gas-bearing active oil in the core is obtained by using the viscosity of the active oil, the length of the core, the pressure at the injection end, and the pressure at the producing end.

[0049] The volume of bound water in the core is calculated based on the volume of formation water at the producing end and the volume of saturated formation water, thereby obtaining the volume of CO2 dissolved in the bound water in the core.

[0050] Based on the volume of gas-bearing oil in the core, the volume of dissolved CO2 in the gas-bearing oil in the core is obtained. The volume of free CO2 in the core is obtained by using the volume of dissolved CO2 in the bound water in the core, the CO2 production rate, and the injection end pressure. Then, the effective permeability of CO2 in the core is calculated by using the CO2 viscosity, the length of the core, the cross-sectional area of ​​the core, the injection end pressure, and the production end pressure.

[0051] The relative permeability of gas-bearing active oil and the relative permeability of CO2 in the core are obtained by using the effective permeability of gas-bearing active oil and the effective permeability of CO2 in the core, respectively, and by using the absolute permeability of the core.

[0052] The present invention has the following beneficial effects:

[0053] Based on the traditional method for determining relative permeability curves, this invention improves the experimental fluid samples and experimental testing methods, fully considering the interactions such as dissolution and diffusion between CO2 and gaseous crude oil under real reservoir conditions, as well as the dissolution and diffusion of CO2 in the aqueous phase, thereby improving the accuracy of relative permeability testing of the CO2-crude oil system under reservoir conditions. Attached Figure Description

[0054] The accompanying drawings, which form part of this application, are used to provide a further understanding of this application. The illustrative embodiments and descriptions of this application are used to explain this application and do not constitute an undue limitation of this application. In the drawings:

[0055] Figure 1 This is a structural diagram of the formation gas-bearing active oil preparation device proposed in an embodiment of the present invention, wherein 1-first injection pump, 2-first valve, 3-heater, 4-rotator, 5-active oil preparation container, 6-second valve, 7-pipeline, 8-active oil temporary storage container, and 9-third valve;

[0056] Figure 2 This is a structural diagram of the CO2 dissolution and diffusion synergistic effect test device for reducing crude oil viscosity proposed in an embodiment of the present invention, wherein 10-second injection pump, 11-fourth valve, 12-fifth valve, 13-first pressure monitoring device, 14-high temperature and high pressure reactor, 15-sixth valve, and 16-high precision live oil viscometer;

[0057] Figure 3 This is a structural diagram of the CO2 solubility measuring device under reservoir conditions proposed in an embodiment of the present invention, wherein 17-third injection pump, 18-seventh valve, 19-first intermediate container, 20-eighth valve, 21-second pressure monitoring device, 22-second intermediate container, and 23-ninth valve;

[0058] Figure 4 This is a structural diagram of the CO2 displacement device containing gas and active oil proposed in an embodiment of the present invention, wherein: 24-fourth injection pump, 25-tenth valve, 26-third intermediate container, 27-eleventh valve, 28-fourth intermediate container, 29-twelfth valve, 30-fifth intermediate container, 31-six-way valve, 32-thirteenth valve, 33-core holder inlet end, 34-containing pressure pump, 35-fourteenth valve, 36-containing pressure liquid inlet end, 37-core holder, 38-core holder outlet end, 39-fifteenth valve, 40-back pressure valve, 41-thermal chamber, 42-fifth injection pump, 43-temperature sensor, 44-pressure sensor, 45-computer system, 46-control system;

[0059] Figure 5 The diagram illustrates an example of the calculation results presented in an embodiment of the present invention. Detailed Implementation

[0060] It should be noted that, unless otherwise specified, the embodiments and features described in the present invention can be combined with each other. The present application will now be described in detail with reference to the accompanying drawings and embodiments.

[0061] It should be noted that the steps shown in the flowchart in the accompanying drawings can be executed in a computer system such as a set of computer-executable instructions, and although a logical order is shown in the flowchart, in some cases the steps shown or described may be executed in a different order than that shown here.

[0062] Currently, existing methods for determining the relative permeability of formation oil and gas use actual crude oil from the formation. These methods measure the solubility, gas-oil ratio, volume factor, and viscosity of the injected gas in the crude oil at formation temperature and a preset pressure. The relative permeability of the injected gas-formation oil is then measured based on the solubility, volume factor, and viscosity of the injected gas-formation oil. While this method tests the solubility characteristics of the injected gas-formation oil under a preset pressure, determines the solubility of the gas phase in the oil phase, and assesses the actual gas saturation in the rock sample, thus improving the accuracy of relative permeability testing, the complex three-phase flow of oil, gas, and water during CO2 injection development in actual oil reservoirs only considers CO2 dissolution in the oil phase, neglecting CO2 dissolution in the water phase and CO2 diffusion in the oil phase. Therefore, this invention addresses these technical problems by proposing a method and system for determining relative permeability that considers the interaction between CO2 and crude oil.

[0063] The following is combined Figure 1-4 The present invention describes a method and system for determining relative permeability considering the interaction between CO2 and crude oil.

[0064] like Figure 1-4As shown, this embodiment provides a relative permeability measurement system that takes into account the interaction between CO2 and crude oil, including: a first configuration device, a first measuring device, a second measuring device, and a first displacement device;

[0065] The first configuration device is used to obtain gas-bearing active oil from the formation;

[0066] The first measuring device is used to obtain the viscosity of the active oil based on the gas-bearing active oil in the formation;

[0067] The second measuring device is used to measure the CO2 solubility in gas-bearing active oil and the CO2 solubility in formation water;

[0068] The first displacement device is used to obtain the relative permeability taking into account the interaction between CO2 and crude oil, based on the viscosity of the live oil, the solubility of CO2 in the gas-bearing live oil, and the solubility of CO2 in the formation water.

[0069] Furthermore, the first configuration device includes a first injection pump, a heater, a live oil configuration container, and a live oil temporary storage container;

[0070] The first injection pump, heater, live oil preparation container and live oil temporary storage container are connected in sequence by pipelines, and several first valve groups are installed in the pipelines, wherein the several first valve groups include a first valve, a second valve and a third valve;

[0071] The first valve is located between the first injection pump and the heater; the second valve is located between the live oil preparation container and the live oil temporary storage container; and the third valve is located at the bottom of the live oil temporary storage container at a certain distance.

[0072] A heater for controlling the temperature of the first preparation device is installed at the top of the live oil preparation container, and rotators for controlling the rotation of the live oil preparation container are installed on both sides of the live oil preparation container.

[0073] Furthermore, the first measuring device includes a second injection pump, a live oil temporary storage container, a first pressure detection device, a high-temperature and high-pressure reactor, and a high-precision live oil viscometer;

[0074] The second injection pump, the live oil temporary storage container, the first pressure detection device, the high temperature and high pressure reactor and the high precision live oil viscometer are connected in sequence through pipelines, and several second valve groups are installed in the pipelines, including the fourth valve, the fifth valve and the sixth valve.

[0075] The fourth valve is located between the second injection pump and the live oil temporary storage container, the fifth valve is located between the live oil temporary storage container and the first pressure detection device, and the sixth valve is located between the high-temperature and high-pressure reactor and the high-precision live oil viscometer.

[0076] Furthermore, the second measuring device includes a third injection pump, a first intermediate container, a second pressure monitoring device, and a second intermediate container;

[0077] The third injection pump, the first intermediate container, the second pressure monitoring device, and the second intermediate container are connected in sequence by pipelines, and several third valve groups are installed in the pipelines, including the seventh valve, the eighth valve, and the ninth valve.

[0078] The seventh valve is located between the third injection pump and the first intermediate container, the eighth valve is located between the first intermediate container and the second pressure monitoring device, and the ninth valve is located at the bottom of the second intermediate container at a certain distance.

[0079] Furthermore, the first displacement device includes a constant temperature chamber, which is equipped with a fourth injection pump, several intermediate containers, a six-way valve, a confining pressure pump, a core holder, a back pressure valve, a fifth injection pump, a temperature sensor, a pressure sensor, and a control subsystem. The control subsystem is connected to a host computer, which is a computer system.

[0080] The fourth injection pump, several intermediate containers, a six-way valve, a core clamp, and a back pressure valve are connected in sequence through pipelines. Among them, several intermediate containers are connected in parallel through pipelines, and the fourth injection pump and each intermediate container are equipped with valves.

[0081] The core holder has an inlet and an outlet at both ends, and a confining pressure fluid inlet at the top. The confining pressure fluid inlet is connected to the fourteenth valve and the confining pressure pump in sequence via pipelines.

[0082] The core holder is equipped with a thirteenth valve and a fifteenth valve at both ends. The thirteenth valve, the pressure sensor, and the fifteenth valve are connected in sequence through pipelines, and the pressure sensor and the core holder are connected in parallel through pipelines.

[0083] The pressure sensor is connected to the control subsystem and the host computer in sequence via pipelines, and the back pressure valve is connected to the fifth injection pump via pipelines.

[0084] Based on the same general inventive concept, this invention also provides a method for determining relative permeability considering the interaction between CO2 and crude oil. The method for determining relative permeability considering the interaction between CO2 and crude oil provided by this invention is described below. The method described below can be referred to in conjunction with the system for determining relative permeability considering the interaction between CO2 and crude oil described above. The method includes the following steps:

[0085] The first configuration device was used to obtain gas-bearing active oil from the formation.

[0086] Based on the active oil containing gas in the formation, the viscosity of the active oil is obtained using the first measuring device;

[0087] The second measuring device was used to obtain the CO2 solubility in gas-bearing active oil and the CO2 solubility in formation water;

[0088] Based on the viscosity of the active oil, the CO2 solubility of the gas-bearing active oil, and the CO2 solubility of the formation water, the relative permeability considering the interaction between CO2 and crude oil is obtained using the first displacement device. The relative permeability considering the interaction between CO2 and crude oil includes the relative permeability of the gas-bearing active oil in the core and the relative permeability of CO2.

[0089] Furthermore, obtaining gas-bearing active oil from the formation using the first configuration device includes:

[0090] Heat the first configuration device to the reservoir temperature;

[0091] Based on the reservoir temperature, degassed dead oil and dissolved gas are injected into the first configuration device to obtain gas-bearing active oil from the formation.

[0092] Specifically, the heater 3 is turned on to heat the entire gas-bearing active oil preparation device to the actual reservoir temperature; the first valve 2 is opened, and the first injection pump 1 is used to inject a certain amount of degassed dead oil and dissolved gas into the active oil preparation container 5 under formation pressure, with the ratio of degassed dead oil to dissolved gas according to the gas-oil ratio of the gas-bearing active oil in the formation; the rotator 4 is turned on to make the active oil preparation container 5 rotate slowly at 360 degrees for 12 hours; the second valve 6 is opened to transfer the prepared gas-bearing active oil from the formation into the active oil temporary storage container 7.

[0093] Furthermore, based on the gas-bearing active oil in the formation, the viscosity of the active oil is obtained using the first measuring device, including:

[0094] Inject gas-bearing active oil from the formation into the first measuring device, and maintain the reservoir pressure and reservoir temperature of the first measuring device;

[0095] Based on reservoir pressure and temperature, the viscosity of the live oil is obtained until the synergistic effect of CO2 dissolution and diffusion in crude oil ends.

[0096] Specifically, the fourth valve 11 and the fifth valve 12 are opened, and the gas-containing active oil prepared in the active oil storage container 8 is injected into the high-temperature and high-pressure reactor 14 using the second injection pump 10. The initial pressure in the high-temperature and high-pressure reactor 14 is maintained at the reservoir pressure, and the temperature is maintained at the reservoir temperature and kept constant. The fifth valve 12 is closed, and the pressure of the high-temperature and high-pressure reactor 14 is monitored by the first pressure monitoring device 13. Since the time required for CO2 to dissolve in crude oil is very limited, and the diffusion of CO2 in crude oil mainly depends on the difference in CO2 concentration between the oil and gas phases, the synergistic effect of CO2 dissolution and diffusion in crude oil is considered to have ended when the reading of the first pressure monitoring device 13 becomes constant. When the reading of the first pressure monitoring device 13 becomes constant, the sixth valve 15 is opened, and the gas-containing active oil in the high-temperature and high-pressure reactor 14 is introduced into the high-precision active oil viscometer 16 to measure the viscosity of the active oil at this moment, which is recorded as μ. 溶扩 .

[0097] Furthermore, the second measuring device is used to obtain the CO2 solubility of gas-bearing active oil and the CO2 solubility of formation water, including:

[0098] To obtain gas-bearing active oil and formation water from the formation;

[0099] Pure CO2 and gas-bearing active oil from the formation are injected into the second measuring device, and the reservoir pressure and temperature in the second measuring device are maintained. After a target time, the first internal pressure is obtained, and then the CO2 solubility of the gas-bearing active oil is obtained.

[0100] Pure CO2 and formation water are injected into the second measuring device, and the reservoir pressure and temperature inside the second measuring device are maintained. After a target time, the second internal pressure is obtained, and then the CO2 solubility in the formation water is obtained.

[0101] Specifically, close the seventh valve 18, the eighth valve 20, and the ninth valve 23, fill the first intermediate container 19 with pure CO2, and fill the second intermediate container 22 with the prepared gas-bearing active oil or formation water, as follows:

[0102] Step 1: Determination of CO2 solubility in gas-bearing activated oil under reservoir conditions: Fill the second intermediate container 22 with the prepared gas-bearing activated oil. Open the seventh valve 18 and the eighth valve 20, and use the third injection pump 17 to pump pure CO2 from the first intermediate container 19 into the second intermediate container 22, while maintaining the reservoir temperature and pressure; close the eighth valve 20, and after 10 minutes, read the internal pressure of the second intermediate container 22 through the second pressure monitoring device 21. Calculate the CO2 solubility per unit volume of gas-bearing activated oil based on the pressure drop, which is R. 原油 for.

[0103] Step 2: Determination of CO2 solubility in formation water under reservoir conditions: Fill the second intermediate container 22 with formation water. Open the seventh valve 18 and the eighth valve 20, and use the third injection pump 17 to pump pure CO2 from the first intermediate container 19 into the second intermediate container 22, while maintaining the reservoir temperature and pressure. Close the eighth valve 20, and after 10 minutes, read the internal pressure of the second intermediate container 22 using the second pressure monitoring device 21. Calculate the solubility of CO2 in formation water per unit volume based on the pressure drop, which is R. 地层水 .

[0104] Furthermore, based on the viscosity of the active oil, the CO2 solubility of the gas-bearing active oil, and the CO2 solubility of the formation water, the relative permeability considering the CO2-crude oil interaction is obtained using the first displacement device, including:

[0105] The core pore volume is calculated by analyzing the core porosity, length, and cross-sectional area, and then the nitrogen and CO2 viscosity at reservoir pressure and temperature are obtained.

[0106] The core is placed in the first displacement device, and the first displacement device is evacuated to reach the target temperature, and the back pressure valve of the first displacement device reaches the first target pressure, and the confining pressure of the first displacement device reaches the second target pressure, thereby obtaining the target back pressure and target flow pressure.

[0107] The volume of nitrogen flowing into the first displacement device is obtained by using nitrogen and the first displacement device, and the absolute permeability of the core is obtained based on the target flow pressure, target back pressure, nitrogen viscosity, core length and cross-sectional area.

[0108] Binding formation water is obtained, and saturated gas-bearing active oil is obtained through the first displacement device. Then, the volume of saturated formation water, the volume of saturated gas-bearing active oil, and the volume of formation water at the producing end are recorded.

[0109] A CO2 displacement experiment was conducted on gas-bearing active oil using the first displacement device to obtain the volume of gas-bearing active oil at the production end, the amount of CO2 injected and the amount of CO2 produced, as well as the pressure at the injection end and the pressure at the production end in the core holder.

[0110] The volume of gas-bearing active oil in the core is calculated by the volume of gas-bearing active oil at the producing end and the volume of saturated gas-bearing active oil. The effective permeability of the gas-bearing active oil in the core is obtained by the viscosity of the active oil, the length of the core, the pressure at the injection end and the pressure at the producing end.

[0111] The volume of bound water in the core is calculated based on the volume of formation water at the producing end and the volume of saturated formation water, thereby obtaining the volume of CO2 dissolved in the bound water in the core.

[0112] Based on the volume of gas-bearing active oil in the core, the volume of dissolved CO2 in the gas-bearing active oil in the core is obtained. The volume of free CO2 in the core is obtained by using the volume of dissolved CO2 in the bound water in the core, the CO2 production rate and the injection end pressure. Then, the effective permeability of CO2 in the core is calculated by using CO2 viscosity, core length, core cross-sectional area, injection end pressure and production end pressure.

[0113] The effective permeability of gas-bearing active oil and the effective permeability of CO2 in the core were obtained by using the effective permeability of gas-bearing active oil and the relative permeability of CO2 in the core, respectively, and by using the absolute permeability of the core.

[0114] Specifically, the third intermediate container 26 contains gas-bearing active oil, the fourth intermediate container 28 contains formation water, and the fifth intermediate container 30 contains nitrogen. The porosity and length of the core are denoted as L, the cross-sectional area as A, and the calculated pore volume as V. 岩石 The viscosity of nitrogen gas at a reservoir temperature of 140℃ and a pressure of 55MPa is given in μ. 氮气 The CO2 viscosity at reservoir temperature and pressure is The steps are as follows:

[0115] Step 1: Pressurize the displacement system above the saturation pressure and calculate the absolute permeability of the core.

[0116] Place the prepared core into the core holder 37, close the back pressure valve 40, open all switches, connect the vacuum pump at the fourth injection pump 24, and evacuate the gas-containing active oil CO2 displacement device for 24 hours to ensure that there is no gas in the experimental system. Use the constant temperature chamber 41 to heat the gas-containing active oil CO2 displacement device to 140℃, and use the temperature sensor 43 to monitor the temperature of the experimental system until it reaches 140℃. Use the fifth injection pump 42 to inject water into the back pressure valve 40, and measure the pressure through the pressure sensor 44 until the back pressure valve 40 rises to the target pressure (above the saturation pressure), denoted as P. 回压 Water is injected into the core holder 37 through the confining pressure pump 34 via the confining pressure inlet 36, and the pressure is measured by the pressure sensor 44 to raise the confining pressure of the experimental system to the target pressure (5 MPa higher than the flowing pressure). Water is then injected into the fifth intermediate container 30 through the twelfth valve 29 via the fourth injection pump 24. Once the pressure in the intermediate container reaches the target pressure (higher than the back pressure), it is denoted as P. 流压 Open the six-way valve 31 to allow nitrogen gas to flow into the core holder 37 through the inlet end 33 of the core holder. Record the volume of nitrogen gas flowing into the CO2 displacement device containing gas as V. 氮气 .

[0117]

[0118] Step 2: Create bound formation water and saturate the core holder with gas-bearing active oil;

[0119] Open the back pressure valve 40 to allow fluid to flow out from the pipeline on the right side of the back pressure valve 40. Based on the fourth injection pump 24 injecting water into the fourth intermediate container 28 through the eleventh valve 27, after its pressure rises to the target pressure (higher than the back pressure), open the six-way valve 31 to allow formation water to flow into the core holder 37 through the inlet end 33 of the core holder, and continue to inject 20 times the core pore volume. It is considered that the formation water binding is completed. Record the volume of saturated formation water as V based on the flow difference between the injection end and the production end in the core holder 37. 束缚水初 Then, based on the fourth injection pump 24 injecting water into the third intermediate container 26 at a low injection rate through the tenth valve 25, after the pressure rises to the target pressure (higher than the back pressure), the six-way valve 31 is opened, allowing the gas-bearing active oil to flow into the core holder 37 through the inlet end 33 of the core holder, and continuously injecting 20 times the core pore volume. It is considered that the gas-bearing active oil is saturated in the core holder. The volume of saturated gas-bearing active oil is recorded as V based on the flow difference between the injection end and the production end in the core holder 37. 含气活油初 And the volume of formation water at the producing end is denoted as V. 束缚水产 .

[0120] Step 3: CO2 displacement experiment of gas-containing active oil;

[0121] The gas inside the fifth intermediate container 30 was replaced with CO2. Water was injected into the fifth intermediate container 30 via the fourth injection pump 24 and the twelfth valve 29. After the pressure in the container reached the reservoir pressure, the six-way valve 31 was opened, allowing CO2 to flow into the core holder 37 through the inlet end 33. This flow was then kept constant for a sufficient time to ensure that CO2 and crude oil fully exchanged components and that CO2 could fully dissolve and diffuse in the gas-bearing active oil. The injection continued for 1.2 times the core pore volume, at which point the CO2 displacement experiment of the gas-bearing active oil was considered complete. During this period, the flow difference between the injection end and the production end in the core holder 37 was constantly monitored, and the volume of gas-bearing active oil at the production end was recorded as V. 含气活油产 The CO2 injection volume is denoted as CO2 production is denoted as The pressure at the injection end of the core holder 37 is recorded as P. 注入 The output pressure is P 产出 .

[0122] Step 4: Calculate the relative permeability curve considering the interaction between carbon dioxide and crude oil using the following formula:

[0123] The volume of bound water in the core is calculated as: V 内水 =V 束缚水初 -V 束缚水产 ;

[0124] Calculate the bound water saturation as S w for:

[0125] The volume of CO2 dissolved in the bound water within the core is calculated as: V 溶于水 =R 地层水 *V 内水 =R 地层水 *(V 束缚水初 -V 束缚水产 );

[0126] The volume of gas-bearing active oil in the core is calculated as: V 内油 =V 含气活油初 -V 含气活油产 ;

[0127] The volume of dissolved CO2 in the gas-bearing active oil within the core is calculated as: V 溶于油 =R 原油 *V 内油 =R 原油 *(V 含气活油初 -V 含气活油产 );

[0128] The volume of free CO2 in the core is calculated as follows:

[0129] Calculate the free CO2 saturation S in the core. g for:

[0130] Calculate the effective permeability K of gas-bearing active oil in the core. 油 for:

[0131] Calculate the effective CO2 permeability in the core. for:

[0132] Calculate the relative permeability K of gas-bearing active oil in the core. 油相 for:

[0133] Calculate the relative permeability of CO2 in the core. for:

[0134] Example

[0135] The following is combined Figure 1-4 The present invention will be described in detail as follows:

[0136] Step 1: As Figure 1As shown, the formation gas-bearing live oil preparation device includes: a first injection pump 1, a first valve 2, a heater 3, a rotator 4, a live oil preparation container 5, a second valve 6, a pipeline 7, a live oil temporary storage container 8, and a third valve 9.

[0137] according to Figure 1 All experimental equipment is connected via pipeline 7. First valve 2, second valve 6, and third valve 9 are all closed. Heater 3 is turned on to raise the temperature of the entire gas-bearing active oil preparation device to the actual reservoir temperature of 140℃. First valve 2 is opened, and first injection pump 1 is used to inject gas into the active oil preparation container 5 at a formation pressure of 55 MPa and a gas-oil ratio of 88.8 cm⁻¹. 3 / cm 3 Inject 200ml of degassed dead oil and dissolved gas; turn on the rotary valve 4 to make the live oil preparation container 5 rotate slowly at 360 degrees for 12 hours; open the second valve 6 and transfer the prepared 200ml of gas-bearing live oil from the formation into the live oil temporary storage container 7.

[0138] Step 2: The CO2 dissolution and diffusion synergistic effect test device for reducing crude oil viscosity includes: a second injection pump 10, a fourth valve 11, a live oil temporary storage container 8, a fifth valve 12, a first pressure monitoring device 13, a high-temperature and high-pressure reactor 14, a sixth valve 15, a high-precision live oil viscometer 16, and pipelines 7.

[0139] according to Figure 2 Connect all experimental equipment via pipeline 7, open the fourth valve 11 and the fifth valve 12, close the sixth valve 15, and use the second injection pump 10 to inject 200 ml of gas-containing active oil prepared in the active oil storage container 8 into the high-temperature and high-pressure reactor 14. Maintain the initial pressure in the high-temperature and high-pressure reactor 14 at the reservoir pressure of 55 MPa and the temperature at the reservoir temperature of 140°C and keep it constant. Close the fifth valve 12 and monitor the pressure of the high-temperature and high-pressure reactor 14 through the first pressure monitoring device 13. Since the time required for CO2 to dissolve in crude oil is very limited, and the diffusion of CO2 in crude oil mainly depends on the difference in CO2 concentration between the oil and gas phases, the synergistic effect of CO2 dissolution and diffusion in crude oil is considered to have ended when the reading of the first pressure monitoring device 13 is constant at 43 MPa. Open the sixth valve 15 and introduce the gas-containing active oil in the high-temperature and high-pressure reactor 14 into the high-precision active oil viscometer 16. The viscosity of the active oil at this moment is measured to be 1.13 mPa·s.

[0140] Step 3: The CO2 solubility measuring device under reservoir conditions includes: a third injection pump 17, a seventh valve 18, a first intermediate container 19, an eighth valve 20, a second pressure monitoring device 21, a second intermediate container 22, a ninth valve 23, and a pipeline 7.

[0141] according to Figure 3Connect all experimental equipment via pipeline 7, close valves 18, 20, and 23, and fill the first intermediate container 19 with pure CO2 and the second intermediate container 22 with prepared gas-bearing active oil or formation water. Specifically:

[0142] Determination of CO2 solubility in gas-bearing activated oil under reservoir conditions: The second intermediate container 22 was filled with 200 ml of prepared gas-bearing activated oil. The seventh valve 18 and the eighth valve 20 were opened, and the pure CO2 from the first intermediate container 19 was pumped into the second intermediate container 22 using the third injection pump 17, maintaining the reservoir temperature at 140℃ and the pressure at 55 MPa. The eighth valve 20 was closed, and after 10 minutes, the internal pressure of the second intermediate container 22 was read using the second pressure monitoring device 21. The pressure drop was then converted into the CO2 solubility R per unit volume of gas-bearing activated oil. 原油 13 mol·L -1 .

[0143] Determination of CO2 solubility in formation water under reservoir conditions: The second intermediate container 22 was filled with formation water. The seventh valve 18 and the eighth valve 20 were opened, and pure CO2 from the first intermediate container 19 was pumped into the second intermediate container 22 using the third injection pump 17, maintaining the reservoir temperature at 140℃ and the pressure at 55MPa. The eighth valve 20 was closed, and after 10 minutes, the internal pressure of the second intermediate container 22 was read using the second pressure monitoring device 21. The pressure drop was then converted into the formation water CO2 solubility R per unit volume. 地层水 4 mol·L -1 .

[0144] Step 4: The CO2 displacement device for gas-bearing active oil includes: a fourth injection pump 24, a tenth valve 25, a third intermediate container 26, an eleventh valve 27, a fourth intermediate container 28, a twelfth valve 29, a fifth intermediate container 30, a six-way valve 31, a thirteenth valve 32, a core holder inlet 33, a confining pressure pump 34, a fourteenth valve 35, a confining pressure fluid inlet 36, a core holder 37, a core holder outlet 38, a fifteenth valve 39, a back pressure valve 40, a constant temperature chamber 41, a fifth injection pump 42, a temperature sensor 43, a pressure sensor 44, a computer system 45, a control system 46, and pipelines 7. The temperature sensor 43 is a built-in device of the constant temperature chamber 41, used to monitor the temperature of the CO2 displacement device for gas-bearing active oil. The entire CO2 displacement device for relative permeability testing needs to be placed in the constant temperature chamber 41 to maintain a constant temperature.

[0145] The experimental system described above is characterized by the following: the third intermediate container 26 contains gas-bearing active oil, the fourth intermediate container 28 contains formation water, and the fifth intermediate container 30 contains nitrogen. The core has a porosity of 0.3, a core length L of 18 cm, and a core cross-sectional area A of 4.91 cm².2 Calculate the core pore volume V 岩石 It is 26.49cm 3 Query the nitrogen viscosity μ at a reservoir temperature of 140℃ and a pressure of 55MPa. 氮气 The CO2 viscosity is 0.03458 mPa·s at the reservoir temperature and pressure. It is 0.06705 mPa·s, specifically:

[0146] Step 1: Pressurize the displacement system above the saturation pressure and calculate the absolute permeability of the core.

[0147] according to Figure 4 Connect all experimental equipment via pipeline 7, then place the prepared core into the core holder 37. Close the back pressure valve 40 and open all switches, namely, open the tenth valve 25, the eleventh valve 27, the twelfth valve 29, the thirteenth valve 32, the fourteenth valve 35, and the fifteenth valve 39. Connect a vacuum pump at the fourth injection pump 24 and evacuate the gas-containing active oil CO2 displacement device for 24 hours to ensure that there is no gas in the experimental system. Use a constant temperature chamber 41 to heat the gas-containing active oil CO2 displacement device to 140°C, and use a temperature sensor 43 to monitor the temperature of the experimental system until it reaches 140°C. Use the fifth injection pump 42 to inject water into the back pressure valve 40, and use a pressure sensor 44 to measure the pressure until the back pressure valve 40 rises to 50 MPa, denoted as P. 回压 Water is injected into the core holder 37 through the confining pressure inlet 36 using the confining pressure pump 34, raising the confining pressure of the experimental system to 60 MPa. Water is then injected into the fifth intermediate container 30 through the twelfth valve 29 using the fourth injection pump 24, and the pressure is measured by the pressure sensor 44. The pressure is recorded as P when it reaches 55 MPa. 流压 Open the six-way valve 31 to allow nitrogen gas to flow into the core holder 37 through the inlet end 33 of the core holder, and record the volume V of nitrogen gas flowing into the CO2 displacement device containing gas. 氮气 It is 1702.33ml.

[0148]

[0149] Step 2: Create bound formation water and saturate the core holder with gas-bearing active oil;

[0150] Open the back pressure valve 40 to allow fluid to flow out from the pipeline on the right side of the back pressure valve 40. Based on the fourth injection pump 24 injecting water into the fourth intermediate container 28 through the eleventh valve 27, after the pressure rises to 55MPa, open the six-way valve 31 to allow formation water to flow into the core holder 37 through the inlet end 33 of the core holder, and continuously inject 529.8ml. It is considered that the formation water binding is completed. Record the volume of saturated formation water, V, by the flow difference between the injection end and the production end in the core holder 37. 束缚水初 The volume was 26.10 ml. Then, based on the fourth injection pump 24, water was injected into the third intermediate container 26 at a lower injection rate through the tenth valve 25. After the pressure rose to 55 MPa, the six-way valve 31 was opened, allowing the gas-bearing active oil to flow into the core holder 37 through the inlet end 33. A total of 529.8 ml was continuously injected, saturating the core holder with gas-bearing active oil. The volume V of the saturated gas-bearing active oil was recorded based on the flow difference between the injection and production ends of the core holder 37. 含气活油初 The volume was 18.27 ml, and the formation water volume at the producing end was V. 束缚水产 It is 7.83ml.

[0151] Step 3: CO2 displacement experiment of gas-containing active oil;

[0152] The gas inside the fifth intermediate container 30 was replaced with CO2. Water was injected into the fifth intermediate container 30 via the fourth injection pump 24 and the twelfth valve 29. After the pressure rose to the reservoir pressure of 55 MPa, the six-way valve 31 was opened, allowing CO2 to flow into the core holder 37 through the inlet end 33. This flow was then kept constant for 72 hours to ensure that CO2 and crude oil fully exchanged components and that CO2 could fully dissolve and diffuse in the gas-bearing active oil. A further 31.8 ml was continuously injected, at which point the CO2 displacement experiment of the gas-bearing active oil was considered complete. During this period, the flow difference between the injection and production ends in the core holder 37 was constantly monitored, and the volume of gas-bearing active oil at the production end was recorded as V. 含气活油产 The CO2 injection volume is denoted as CO2 production is denoted as The pressure at the injection end of the core holder 37 is recorded as P. 注入 The output pressure is P 产出 .

[0153] Step 4: Calculate the relative permeability curve considering the interaction between carbon dioxide and crude oil using the following formula:

[0154] The volume of bound water in the core is calculated as: V 内水 =V 束缚水初 -V 束缚水产 ;

[0155] Calculate the bound water saturation as S w for:

[0156] The volume of CO2 dissolved in the bound water within the core is calculated as: V 溶于水 =R 地层水 *V 内水 =R 地层水 *(V 束缚水初 -V 束缚水产 );

[0157] The volume of gas-bearing active oil in the core is calculated as: V 内油 =V 含气活油初 -V 含气活油产 ;

[0158] The volume of dissolved CO2 in the gas-bearing active oil within the core is calculated as: V 溶于油 =R 原油 *V 内油 =R 原油 *(V 含气活油初 -V 含气活油产 );

[0159] The volume of free CO2 in the core is calculated as follows:

[0160] Calculate the free CO2 saturation S in the core. g for:

[0161] Calculate the effective permeability K of gas-bearing active oil in the core. 油 for:

[0162] Calculate the effective CO2 permeability in the core. for:

[0163] Calculate the relative permeability K of gas-bearing active oil in the core. 油相 for:

[0164] Calculate the relative permeability of CO2 in the core. for:

[0165] like Figure 5As shown in the example diagram, the calculation results demonstrate that the method employed in this invention improves the accuracy of relative permeability testing of the CO2-crude oil system under reservoir conditions. Specifically, this invention improves upon traditional methods for determining relative permeability curves by modifying the experimental fluid samples and testing methods. It fully considers the interactions between CO2 and gaseous crude oil under real reservoir conditions, including dissolution and diffusion, as well as the dissolution and diffusion of CO2 in the aqueous phase, thereby enhancing the accuracy of relative permeability testing of the CO2-crude oil system under reservoir conditions.

[0166] The above description is merely a preferred embodiment of this application, but the scope of protection of this application is not limited thereto. Any variations or substitutions that can be easily conceived by those skilled in the art within the technical scope disclosed in this application should be included within the scope of protection of this application. Therefore, the scope of protection of this application should be determined by the scope of the claims.

Claims

1. Consider - A method for determining the relative permeability of crude oil interactions, characterized in that, Specifically, the following steps are included: The first configuration device was used to obtain gas-bearing active oil from the formation. Based on the gas-bearing active oil in the formation, the viscosity of the active oil is obtained using a first measuring device; Gas-containing active oil was obtained using the second measuring device. Solubility and formation water Solubility; Based on the viscosity of the active oil and the gas-containing active oil Solubility and the formation water Solubility, obtained using the first displacement device. - The relative penetration rate of crude oil interactions, wherein the considerations - The relative permeability of crude oil interactions includes the relative permeability of gas-bearing active oil within the core and Relative permeability: The core pore volume is calculated using the core's porosity, length, and cross-sectional area. This allows for the determination of nitrogen viscosity at reservoir pressure and temperature. Viscosity; The core is placed in the first displacement device, the first displacement device is evacuated to reach the target temperature, the back pressure valve of the first displacement device reaches the first target pressure, and the confining pressure of the first displacement device reaches the second target pressure, thereby obtaining the target back pressure and the target flow pressure. The volume of nitrogen flowing into the first displacement device is obtained by using nitrogen and the first displacement device, and the absolute permeability of the core is obtained based on the target flow pressure, the target back pressure, the nitrogen viscosity, the length and cross-sectional area of ​​the core. Binding formation water is obtained, and saturated gas-bearing active oil is obtained through the first displacement device. Then, the volume of saturated formation water, the volume of saturated gas-bearing active oil, and the volume of formation water at the producing end are recorded. Using the first displacement device to activate gas-containing oil Displacement experiments were conducted to obtain the volume of gas-containing active oil at the producing end. Injection volume and Production volume and the injection end pressure and output end pressure in the core holder; The volume of gas-bearing active oil in the core is calculated using the volume of gas-bearing active oil at the producing end and the volume of saturated gas-bearing active oil. And through the viscosity of the active oil The length L of the core and the injection end pressure and the output end pressure Calculate the effective permeability of gas-bearing active oil in the core. : ,in, This represents the cross-sectional area of ​​the rock core. The volume of bound water in the core is calculated based on the volume of formation water at the producing end and the volume of saturated formation water, thereby obtaining the dissolved water in the bound water within the core. volume; Based on the volume of gas-bearing active oil in the core, obtain the dissolved... Volume, and through the water dissolved in the core. Volume, the aforementioned Output and the injection end pressure Obtain free samples from the core. volume And thus through the Viscosity The length of the core The cross-sectional area of ​​the core The injection end pressure and the output end pressure Calculate the contents of the core Effective penetration rate for: ,in, for Injection volume, Formation water per unit volume Solubility The volume of saturated formation water. For the volume of formation water at the producing end, Gas-containing active oil per unit volume Solubility The volume of saturated gas-containing active oil. The volume of gas-bearing active oil at the production end; The effective permeability of gas-bearing active oil in the core and the core content were respectively measured by the effective permeability of gas-bearing active oil in the core. The effective permeability, and using the absolute permeability of the core, the relative permeability of the gas-bearing active oil in the core and the permeability of the core are obtained. The relative penetration rate.

2. Considerations as described in claim 1 - A method for determining the relative permeability of crude oil interactions, characterized in that, Obtaining gas-bearing active oil from the formation using the first configuration device includes: Heat the first configuration device to the reservoir temperature; Based on the reservoir temperature, degassed dead oil and dissolved gas are injected into the first configuration device to obtain gas-bearing active oil from the formation.

3. Considerations as described in claim 2 - A method for determining the relative permeability of crude oil interactions, characterized in that, Based on the gas-bearing active oil in the formation, the viscosity of the active oil obtained using the first measuring device includes: The gas-bearing active oil in the formation is injected into the first measuring device, and the reservoir pressure and reservoir temperature of the first measuring device are maintained. Based on the reservoir pressure and the reservoir temperature, until The synergistic effect of dissolution and diffusion in crude oil ends, thereby obtaining the viscosity of the live oil.

4. Considerations as described in claim 3 - A method for determining the relative permeability of crude oil interactions, characterized in that, The gas-containing active oil was obtained using the second measuring device. Solubility and the formation water Solubility includes: Obtain gas-bearing active oil and formation water from the formation; Pure The gas-bearing active oil from the formation is injected into the second measuring device, and the reservoir pressure and temperature within the second measuring device are maintained. After a target time, the first internal pressure is obtained, and then the gas-bearing active oil is obtained. Solubility; The pure The formation water is injected into the second measuring device, and the reservoir pressure and temperature within the second measuring device are maintained. After the target time, the second internal pressure is obtained, and then the formation water is obtained. Solubility.

5. Considerations as described in claim 1 - A method for determining the relative permeability of crude oil interactions, characterized in that, The measurement system for implementing the method includes: a first configuration device, a first measuring device, a second measuring device, and a first displacement device; The first configuration device is used to obtain gas-bearing active oil from the formation; The first measuring device is used to obtain the viscosity of the active oil based on the gas-bearing active oil in the formation; The second measuring device is used to measure gas-containing active oil. Solubility and formation water Solubility; The first displacement device is used to determine the viscosity of the active oil and the gas-containing active oil. Solubility and the formation water Solubility, acquisition considerations - Relative penetration rate of crude oil interactions.

6. Considerations as described in claim 5 - A method for determining the relative permeability of crude oil interactions, characterized in that, The first configuration device includes a first injection pump, a heater, a live oil configuration container, and a live oil temporary storage container; The first injection pump, the heater, the live oil preparation container and the live oil temporary storage container are connected in sequence by pipelines, and a plurality of first valve groups are provided in the pipelines, wherein the plurality of first valve groups include a first valve, a second valve and a third valve; The first valve is located between the first injection pump and the heater, the second valve is located between the live oil preparation container and the live oil storage container, and the third valve is located at the bottom of the live oil storage container at a certain distance. The live oil preparation container is equipped with a heater at the top to control the temperature of the first preparation device, and rotators are installed on both sides of the live oil preparation container to control its rotation.

7. Considerations as described in claim 5 - A method for determining the relative permeability of crude oil interactions, characterized in that, The first measuring device includes a second injection pump, a live oil storage container, a first pressure monitoring device, a high-temperature and high-pressure reactor, and a high-precision live oil viscometer; The second injection pump, the live oil temporary storage container, the first pressure monitoring device, the high-temperature and high-pressure reactor, and the high-precision live oil viscometer are connected in sequence through pipelines, and a plurality of second valve groups are provided in the pipelines, wherein the plurality of second valve groups include a fourth valve, a fifth valve, and a sixth valve; The fourth valve is located between the second injection pump and the live oil temporary storage container, the fifth valve is located between the live oil temporary storage container and the first pressure monitoring device, and the sixth valve is located between the high-temperature and high-pressure reactor and the high-precision live oil viscometer.

8. Considerations as described in claim 5 - A method for determining the relative permeability of crude oil interactions, characterized in that, The second measuring device includes a third injection pump, a first intermediate container, a second pressure monitoring device, and a second intermediate container; The third injection pump, the first intermediate container, the second pressure monitoring device, and the second intermediate container are connected in sequence by pipelines, and a plurality of third valve groups are provided in the pipelines, wherein the plurality of third valve groups include a seventh valve, an eighth valve, and a ninth valve; The seventh valve is located between the third injection pump and the first intermediate container, the eighth valve is located between the first intermediate container and the second pressure monitoring device, and the ninth valve is located at the bottom of the second intermediate container at a certain distance.

9. Considerations as described in claim 5 - A method for determining the relative permeability of crude oil interactions, characterized in that, The first displacement device includes a constant temperature chamber, which is equipped with a fourth injection pump, several intermediate containers, a six-way valve, a confining pressure pump, a core holder, a back pressure valve, a fifth injection pump, a temperature sensor, a pressure sensor, and a control subsystem. The control subsystem is connected to a host computer, which is a computer system. The fourth injection pump, several intermediate containers, the six-way valve, the core clamp, and the back pressure valve are connected in sequence via pipelines. Several intermediate containers are connected in parallel via the pipelines, and each intermediate container is equipped with a valve. The core holder has a core holder inlet and a core holder outlet at both ends, and a confining pressure fluid inlet at the top. The confining pressure fluid inlet is connected to the fourteenth valve and the confining pressure pump in sequence through the pipeline. The core holder is equipped with a thirteenth valve and a fifteenth valve at both ends. The thirteenth valve, the pressure sensor, and the fifteenth valve are connected in sequence through the pipeline, and the pressure sensor and the core holder are connected in parallel through the pipeline. The pressure sensor is connected to the control subsystem and the host computer in sequence through the pipeline, and the back pressure valve is connected to the fifth injection pump through the pipeline.

Images