Well-ground linkage CO2 flooding crude oil foam performance detection system, method and controller

Abstract

This invention provides a well-to-surface integrated CO2-driven crude oil foam performance testing system, method, and controller. The system includes: a gas supply and pressurization unit that pressurizes the CO2 gas to a predetermined saturation pressure and delivers it to a high-pressure dissolved gas unit; the high-pressure dissolved gas unit simulates underground conditions, saturating and stirring the crude oil solution with CO2 gas at a preset temperature and saturation pressure, and delivering the stirred fluid to a depressurization and desorption foaming unit through a bottom outlet; the depressurization and desorption foaming unit simulates surface conditions, visually displaying the foaming process of the stirred fluid to complete foam performance testing. This achieves dynamic simulation of the entire process from underground high-pressure dissolved gas to surface depressurization and separation, realistically reproducing the flow process from the wellbore to the surface, and realizing the dynamic evolution simulation of foam-containing fluid in pipelines and adjustable separators. This allows for continuous and quantitative evaluation of the foaming characteristics and foam stability of CO2-driven crude oil, providing precise basis for surface process optimization.

Description

Technical Field

[0001] This invention relates to the field of CO2 flooding oil production technology, and in particular to a well-ground integrated CO2 flooding crude oil foam performance testing system, method and controller. Background Technology

[0002] CO2 flooding, a key technology for enhancing oil recovery, produces fluids with pronounced foamy characteristics during the depressurization process in the wellbore and surface pipelines. The presence of these foams severely impacts the stable operation of surface equipment (such as metering separators and production separators), leading to decreased separation efficiency, reduced processing capacity, and even production safety accidents. Therefore, accurately evaluating the foaming characteristics and foam stability of CO2-flooded crude oil is crucial for ensuring the safe and efficient operation of surface processes.

[0003] Currently, evaluation methods for the foaming characteristics of crude oil in CO2-driven flooding are mainly divided into the gas flow method and the depressurization foaming method. The gas flow method has a simple apparatus, generating foam by blowing CO2 gas into the crude oil. However, its nucleation mechanism differs fundamentally from the foam formed by gas precipitation during the depressurization process of CO2-driven produced fluid, thus limiting its application. The depressurization foaming method is closer to reality. Its process involves saturating the crude oil with CO2 in a pressure vessel, and then observing the formation and decay of foam by controlling the depressurization rate, thus gaining widespread application. However, existing depressurization foaming devices and methods mainly evaluate foam behavior under ground conditions, neglecting underground high-pressure conditions, resulting in a disconnect between evaluation conditions and actual process flows. During saturated CO2 and subsequent depressurization processes, existing devices typically keep the fluid stationary, which does not match the situation in actual production where the fluid is always in a flowing state. Existing evaluation devices are mostly single visible containers, while actual production is a continuous process in flow. The complex evolution of foam in this process cannot be realistically reproduced in a single container, making it impossible to simulate the complete process chain. Furthermore, it is impossible to change the structure or operating parameters of the separator according to actual process requirements, resulting in weak guidance of experimental results and difficulty in fully revealing the intrinsic mechanism of foam stability.

[0004] In summary, existing CO2-driven crude oil foaming characteristic evaluation technologies, especially the widely used depressurization foaming method, suffer from significant differences between their evaluation conditions, experimental procedures, and equipment construction and the actual field process. Furthermore, the evaluation parameters are not systematic enough, making it difficult to accurately guide the design and operation optimization of oilfield surface equipment. Summary of the Invention

[0005] One objective of this invention is to provide a well-to-surface integrated CO2-enhanced crude oil foam performance testing system. This system achieves dynamic simulation of the entire process from underground high-pressure gas dissolution to surface depressurization and separation, realistically reproducing the flow process from the wellbore to the surface. It simulates the dynamic evolution of foam-containing fluid in pipelines and adjustable separators, thereby enabling continuous and quantitative evaluation of the foaming characteristics and foam stability of CO2-enhanced crude oil, providing precise data for surface process optimization. Another objective of this invention is to provide a well-to-surface integrated CO2-enhanced crude oil foam performance testing method. A further objective of this invention is to provide a computer-readable medium. A final objective of this invention is to provide a computer device.

[0006] To achieve the above objectives, this invention discloses a well-to-surface integrated CO2-driven crude oil foam performance testing system, comprising: a gas supply and pressurization unit, a high-pressure gas dissolving unit, and a depressurization and desorption foaming unit; wherein the gas supply and pressurization unit is connected to the high-pressure gas dissolving unit, and the high-pressure gas dissolving unit is connected to the depressurization and desorption foaming unit;

[0007] The gas supply and pressurization unit is used to increase the current pressure to a predetermined saturation pressure and deliver CO2 gas to the high-pressure dissolved gas unit;

[0008] The high-pressure dissolved gas unit is used to simulate underground conditions. Under the preset temperature and saturation pressure, the crude oil solution is saturated with CO2 gas, and the saturated fluid is stirred. The stirred fluid is then transported to the depressurization desorption foaming unit through the bottom outlet.

[0009] The depressurization desorption foaming unit is used to simulate ground conditions and visualize the foaming process of the stirred fluid in order to complete the foam performance test.

[0010] Preferably, the gas supply and pressurization unit includes a CO2 cylinder, a first one-way valve, a gas booster device, a first pressure gauge, and a second one-way valve;

[0011] The CO2 cylinder is used to store CO2 gas, and the unidirectional delivery of CO2 gas is controlled by a first one-way valve.

[0012] The gas booster device is used to increase the current pressure to the saturation pressure;

[0013] The first pressure gauge is used to measure and display the current pressure. If the current pressure reaches the saturation pressure, the unidirectional delivery of CO2 gas is controlled by the second one-way valve.

[0014] Preferably, the air supply and pressurization unit further includes an air compressor;

[0015] The air compressor is used to provide a power source for the gas booster device.

[0016] Preferably, the gas supply and pressurization unit further includes: a control valve;

[0017] The control valve is used to control the delivery of CO2 gas from the gas supply and pressurization unit to the high-pressure dissolved gas unit.

[0018] Preferably, the high-pressure dissolved gas unit includes: a high-temperature and high-pressure reactor, a second pressure gauge, a thermometer, an automatic pressure stabilizing device, a temperature control device, and a dynamic regulating drainage device;

[0019] The high-temperature and high-pressure reactor provides space for the crude oil solution and CO2 gas to be saturated, and stirs the saturated fluid.

[0020] The second pressure gauge is used to detect the real-time pressure of the high-temperature and high-pressure reactor;

[0021] The thermometer is used to detect the real-time temperature of the high-temperature and high-pressure reactor;

[0022] The automatic pressure stabilizing device is used to control the pressure of the high-temperature and high-pressure reactor.

[0023] The temperature control device is used to control the temperature of the high-temperature and high-pressure reactor.

[0024] The dynamic adjustment drainage device is used to control the flow of the stirred fluid through the bottom outlet of the high-temperature and high-pressure reactor to the depressurization desorption foaming unit.

[0025] Preferably, the high-temperature and high-pressure reactor includes: a speed sensor, a torque sensor, a stirrer, and an observation window;

[0026] The torque sensor is used to obtain the torque of the stirrer;

[0027] The speed sensor is used to obtain the speed of the stirrer;

[0028] The agitator is used to agitate the saturated fluid according to the calculated agitation parameters, which are determined based on the agitator's torque, rotation speed, acquired wellbore pipe parameters, and reactor internal parameters.

[0029] The observation window is used to visualize the stirring process of the saturated fluid.

[0030] Preferably, the depressurization desorption foaming unit includes: an adjustable pressure reducing component, a visual high-pressure reactor, a liquid flow regulating valve, and a third pressure gauge;

[0031] The adjustable pressure reduction component is used to reduce the pressure of the stirred fluid according to predetermined pressure reduction parameters.

[0032] The visualized high-pressure reactor has an adjustable structure, providing space for the foaming process of the fluid after depressurization and allowing for visualization. The visualized high-pressure reactor provides a sudden expansion space for the fluid after depressurization, simulating a ground separator environment. The simulated ground separator includes a production separator and a metering separator.

[0033] The liquid flow regulating valve is used to control the flow rate of the fluid discharged;

[0034] The third pressure gauge is used to detect the real-time pressure of the visualized high-pressure reactor.

[0035] Preferably, the depressurization desorption foaming unit further includes: a visualized pipe section;

[0036] The visualized pipe section is installed on the connecting pipe section between the pressure-reducing desorption foaming unit and the high-pressure dissolved gas unit.

[0037] Alternatively, it can be located at the inlet of the visualized high-pressure reactor, or at the wellhead location;

[0038] The visualization pipe section is used to visualize the foaming process at different locations as the fluid flows from the wellbore to the surface after decompression treatment.

[0039] Preferably, the depressurization desorption foaming unit further includes: a gas flow regulating valve;

[0040] The gas flow regulating valve is used to control the flow rate of the discharged gas.

[0041] Preferably, the system further includes: a camera device;

[0042] The camera device is used to collect real-time visual data of the foaming process of fluid inside the high-pressure reactor.

[0043] This invention also discloses a well-to-surface integrated CO2 flooding crude oil foam performance testing method, applied to the method described above, comprising:

[0044] Obtain operating parameters and production well parameters;

[0045] Based on the operating parameters and production well parameters, the saturation pressure is generated;

[0046] The crude oil solution is injected into the high-temperature and high-pressure reactor of the high-pressure dissolved gas unit, and the gas supply and pressurization unit is started according to the saturation pressure to deliver CO2 gas to the high-temperature and high-pressure reactor.

[0047] The crude oil solution is saturated with CO2 gas in the high-temperature and high-pressure reactor at a preset temperature and saturation pressure. The saturated fluid is stirred according to the calculated stirring parameters. The stirred fluid is then transported to the visualized high-pressure reactor of the depressurization desorption foaming unit through the bottom outlet.

[0048] Foam performance is tested based on the foaming process inside the visualized high-pressure reactor, and foam performance indicators are generated.

[0049] Preferably, the stirring parameters include: average shear rate of the wellbore pipe, average shear rate of the fluid inside the vessel, and power of the vessel shaft;

[0050] The method further includes:

[0051] Based on different working conditions and the obtained wellbore and pipeline parameters, the average shear rate of the wellbore and pipeline is generated.

[0052] Based on the obtained parameters inside the reactor, the average shear rate of the fluid inside the reactor is generated.

[0053] The reactor shaft power is generated based on the average shear rate of the wellbore pipe.

[0054] Preferably, generating the reactor shaft power based on the average shear rate of the wellbore pipe includes:

[0055] pass The average shear rate of the wellbore pipe is determined as the reactor shaft power, where, For flow pattern correction factor, n The flow characteristic index is the power-law equation. V The average flow velocity of the fluid. ρ The average density of the fluid. f As the friction factor, D The inner diameter of the pipe. K Let be the consistency coefficient of the power-law fluid. P This refers to the power of the reactor shaft.

[0056] Preferably, the foam performance indicators include foaming characteristic indicators and foam stability indicators;

[0057] The process of detecting foam performance based on the visualized foaming process within the high-pressure reactor and generating foam performance indicators includes:

[0058] Based on the visualized foaming process inside the high-pressure reactor, the foaming parameters and foam parameters are determined.

[0059] Based on the foaming parameters, foaming characteristics are tested to generate foaming characteristic indicators, including initial bubble point pressure, foaming index, maximum foaming height, and the change of foam volume over time during the foaming stage.

[0060] Based on the foam parameters, foam stability is tested to generate foam stability indices, including half-life, foam bursting index, and the change in foam volume over time after the foam reaches its maximum volume.

[0061] Preferably, the method further includes:

[0062] Calculate the solubility of CO2 in crude oil;

[0063] Based on the solubility of CO2 in crude oil and the predetermined nuclear threshold pressure, the volume of gas inside the foam under non-equilibrium conditions is generated.

[0064] Based on the relationship between the solubility of CO2 in crude oil, the nuclear threshold pressure, and the volume of gas inside the foam during depressurization desorption, a non-equilibrium foam volume evolution model is constructed.

[0065] The present invention also discloses a controller, comprising:

[0066] The acquisition unit is used to acquire operating parameters and production well parameters.

[0067] The saturation pressure production unit is used to generate saturation pressure based on operating parameters and production well parameters.

[0068] The pressurization unit is used to inject crude oil solution into the high-temperature and high-pressure reactor of the high-pressure dissolved gas unit. The gas supply and pressurization unit is started according to the saturation pressure to deliver CO2 gas to the high-temperature and high-pressure reactor.

[0069] The foam reaction unit is used to saturate crude oil solution with CO2 gas in a high-temperature and high-pressure reactor at a preset temperature and saturation pressure, and to stir the saturated fluid according to the calculated stirring parameters. The stirred fluid is then transported to the visualized high-pressure reactor of the depressurization desorption foaming unit through the bottom outlet.

[0070] The performance testing unit is used to test the foam performance based on the foaming process inside the visualized high-pressure reactor and generate foam performance indicators.

[0071] The present invention also discloses a computer-readable medium having a computer program stored thereon, which, when executed by a processor, implements the method described above.

[0072] The present invention also discloses a computer device, including a memory and a processor, wherein the memory is used to store information including program instructions, and the processor is used to control the execution of the program instructions, and the processor implements the method described above when executing the program.

[0073] The present invention also discloses a computer program product, including a computer program / instruction, which, when executed by a processor, implements the method described above.

[0074] The system of this invention includes: a gas supply and pressurization unit, a high-pressure dissolved gas unit, and a depressurization desorption foaming unit; the gas supply and pressurization unit is connected to the high-pressure dissolved gas unit, and the high-pressure dissolved gas unit is connected to the depressurization desorption foaming unit; the gas supply and pressurization unit is used to increase the current pressure to a predetermined saturation pressure and deliver CO2 gas to the high-pressure dissolved gas unit; the high-pressure dissolved gas unit is used to simulate underground conditions, saturate the crude oil solution with CO2 gas at a preset temperature and saturation pressure, and stir the saturated fluid, delivering the stirred fluid to the depressurization desorption foaming unit through the bottom outlet; the depressurization desorption foaming unit is used to simulate surface conditions, visualize the foaming process of the stirred fluid to complete foam performance testing, and realize the dynamic simulation of the entire process from underground high-pressure dissolved gas to surface depressurization separation, realistically reproducing the flow process from the wellbore to the surface, realizing the dynamic evolution simulation of foam-containing fluid in pipelines and adjustable separators, thereby completing the continuous and quantitative evaluation of the foaming characteristics and foam stability of CO2-driven crude oil, providing accurate basis for surface process optimization. Attached Figure Description

[0075] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0076] Figure 1 This is a schematic diagram of a well-to-surface integrated CO2 flooding crude oil foam performance testing system provided in an embodiment of the present invention;

[0077] Figure 2 A flowchart of a well-to-surface integrated CO2 flooding crude oil foam performance testing method provided in this embodiment of the invention;

[0078] Figure 3 A flowchart illustrating another well-to-surface integrated CO2 flooding crude oil foam performance testing method provided in this embodiment of the invention;

[0079] Figure 4 This is a schematic diagram of the structure of a well-to-surface integrated CO2 flooding crude oil foam performance testing device provided in an embodiment of the present invention;

[0080] Figure 5 This is a schematic diagram of the structure of a computer device provided in an embodiment of the present invention. Detailed Implementation

[0081] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0082] To facilitate understanding of the technical solution provided in this application, the relevant content of the technical solution will be explained below. This invention can conduct foaming characteristic tests considering the flow process during the dynamic depressurization process of CO2-driven crude oil under different conditions based on actual field working conditions, and can quantitatively evaluate the foaming characteristics and foam stability of CO2-driven crude oil. Through the cooperation of multiple modules, namely, using a high-pressure dissolved gas unit to simulate underground (high pressure inside the wellbore) conditions and a depressurization desorption foaming unit to simulate surface (lower than wellhead back pressure) conditions, and setting the device structure and related parameters according to actual field working conditions, considering the foam-containing flow process under underground high pressure and surface low pressure conditions, the foaming characteristics and foam stability of crude oil under underground conditions, surface pipelines, and surface separators can be dynamically evaluated, enabling continuous dynamic evaluation of the foaming characteristics and foam stability of crude oil produced both underground and above-ground.

[0083] Figure 1 This is a schematic diagram of a well-to-surface linked CO2 flooding crude oil foam performance testing system provided in an embodiment of the present invention, as shown below. Figure 1 As shown, the system can reproduce the actual process and fluid flow process within the device. The system includes: a gas supply and pressurization unit 100, a high-pressure dissolved gas unit 200, and a depressurization desorption foaming unit 400; the gas supply and pressurization unit 100 is connected to the high-pressure dissolved gas unit 200, and the high-pressure dissolved gas unit 200 is connected to the depressurization desorption foaming unit 400.

[0084] Specifically, the bottom outlet of the high-pressure dissolved gas unit 200 is connected to the depressurization desorption foaming unit 400 via a pipeline. The pipeline includes an adjustable pressure-reducing component to control the fluid pressure and a visualization section for observing the fluid state.

[0085] The gas supply pressurization unit 100 is used to increase the current pressure to a predetermined saturation pressure and deliver CO2 gas to the high-pressure dissolved gas unit 200.

[0086] The high-pressure dissolved gas unit 200 is used to simulate underground conditions. Under preset temperature and saturation pressure, the crude oil solution is saturated with CO2 gas, and the saturated fluid is stirred. The stirred fluid is then transported to the depressurization desorption foaming unit through the bottom outlet.

[0087] Among them, the crude oil solution is crude oil or oil-water emulsion, and the underground conditions are high-pressure conditions inside the wellbore.

[0088] The depressurization desorption foaming unit 400 is used to simulate ground conditions and visualize the foaming process of the stirred fluid in order to complete the foam performance test.

[0089] Among them, the ground conditions are those lower than the wellhead back pressure.

[0090] In this embodiment of the invention, each unit sets the device structure and related parameters according to the actual working conditions on site, thereby clearly considering the flow process of foam-containing fluid under underground high pressure and ground low pressure conditions.

[0091] like Figure 1 As shown, the gas supply and pressurization unit 100 includes a CO2 cylinder 110, a first one-way valve 120, a gas pressurization device 130, a first pressure gauge 140, and a second one-way valve 150.

[0092] CO2 cylinder 110 is used to store CO2 gas. The first one-way valve 120 controls the one-way delivery of CO2 gas to prevent gas backflow.

[0093] The gas booster 130 receives CO2 gas from the CO2 cylinder 110 and increases its current pressure to a predetermined saturation pressure.

[0094] The first pressure gauge 140 is used to measure and display the current pressure in real time. If the current pressure reaches the saturation pressure, the second one-way valve 150 controls the unidirectional delivery of CO2 gas. Specifically, when the first pressure gauge 140 shows that the current pressure has reached the saturation pressure, the second one-way valve 150 opens, allowing CO2 gas to be delivered unidirectionally to the high-pressure dissolved gas unit 200 at the saturation pressure, ensuring the stability and controllability of the gas supply pressure.

[0095] In this embodiment of the invention, the saturation pressure varies depending on the research objective. It is mainly divided into two categories based on the research node: the initial saturation pressure starting from the underground and the surface pipeline.

[0096] like Figure 1 As shown, the air supply and pressurization unit 100 also includes an air compressor 160; the air compressor 160 is used to provide a power source for the gas pressurization device 130.

[0097] Specifically, the air compressor 160 is connected to the gas booster device 130, and is used to provide compressed air to the gas booster device 130 as a power source to drive its normal operation.

[0098] like Figure 1 As shown, the gas supply and pressurization unit 100 also includes a control valve 170; the control valve 170 is used to control the delivery of CO2 gas from the gas supply and pressurization unit 100 to the high-pressure dissolved gas unit 200.

[0099] Specifically, the control valve 170 is located at the final outlet of the gas supply and pressurization unit 100 and is used to precisely control the on / off supply and flow rate of CO2 gas from the gas supply and pressurization unit 100 to the high-pressure dissolved gas unit 200.

[0100] Through the coordinated operation of the above components, the gas supply and pressurization unit 100 can continuously and stably provide the high-pressure dissolved gas unit 200 with CO2 gas to reach the required saturation pressure.

[0101] like Figure 1 As shown, the high-pressure dissolved gas unit 200 includes: a high-temperature and high-pressure reactor 210, a second pressure gauge 220, a thermometer 230, an automatic pressure stabilizing device 240, a temperature control device 250, and a dynamic adjustment drainage device 260.

[0102] The high-temperature and high-pressure reactor 210 provides space for the crude oil solution and CO2 gas to be saturated, and stirs the saturated fluid.

[0103] In this embodiment of the invention, the high-temperature and high-pressure reactor 210 is the core container of the unit, containing crude oil or an oil-water emulsion and C The gas is provided to be fully saturated at a predetermined temperature and pressure. Once saturated, an internal agitator stirs the fluid to simulate the flow shearing process in underground wells or pipes.

[0104] The second pressure gauge 220 is used to detect the real-time pressure of the high-temperature and high-pressure reactor 210.

[0105] In this embodiment of the invention, the second pressure gauge 220 is installed on the high-temperature and high-pressure reactor 210 to detect and display the pressure data inside the reactor in real time.

[0106] Thermometer 230 is used to detect the real-time temperature of high-temperature and high-pressure reactor 210.

[0107] In this embodiment of the invention, thermometer 230 is installed on high-temperature and high-pressure reactor 210 to detect and display the temperature data inside the reactor in real time.

[0108] The automatic pressure stabilizing device 240 is used to control the pressure of the high-temperature and high-pressure reactor 210.

[0109] In this embodiment of the invention, the automatic pressure stabilizing device 240 is connected to the high-temperature and high-pressure reactor 210. Based on the feedback from the second pressure gauge 220, it dynamically adjusts the intake or exhaust of air to precisely control the pressure inside the reactor at a predetermined saturation pressure.

[0110] Temperature control device 250 is used to control the temperature of high temperature and high pressure reactor 210.

[0111] In this embodiment of the invention, the temperature control device 250 is used to circulate the heating or cooling medium and control the temperature inside the high-temperature and high-pressure reactor 210 to stabilize it at the set value required for the experiment.

[0112] The dynamic adjustment drainage device 260 is used to control the flow of the stirred fluid through the bottom outlet of the high-temperature and high-pressure reactor to the depressurization desorption foaming unit.

[0113] In this embodiment of the invention, the dynamic adjustment drainage device 260 is connected to the bottom outlet of the high-temperature and high-pressure reactor 210, and is used to control the fluid delivery rate to the depressurization desorption foaming unit 400 after the saturation and stirring processes are completed.

[0114] like Figure 1 As shown, the high-temperature and high-pressure reactor 210 includes: a speed sensor 270, a torque sensor 280, a stirrer 290, and an observation window 300.

[0115] Torque sensor 280 is used to obtain the torque of stirrer 290.

[0116] In this embodiment of the invention, the torque sensor 280 is used to acquire the torque of the stirring shaft when the stirrer 290 is working in real time.

[0117] The speed sensor 270 is used to obtain the speed of the stirrer 290.

[0118] In this embodiment of the invention, the speed sensor 270 is used to acquire the speed of the impeller of the stirrer 290 in real time when it is working.

[0119] The agitator 290 is used to agitate the saturated fluid according to the calculated agitation parameters, which are determined based on the agitator's torque, rotation speed, acquired wellbore pipe parameters, and reactor internal parameters.

[0120] In this embodiment of the invention, the stirrer 290 serves as the agitator, stirring the saturated fluid according to calculated stirring parameters. These stirring parameters are determined based on data obtained from torque and speed sensors or the input power and efficiency of the motor, combined with actual wellbore and pipeline parameters and fluid parameters within the reactor, aiming to accurately simulate the flow shear conditions within the wellbore or pipeline.

[0121] View window 300 is used to visualize the stirring process of a saturated fluid.

[0122] In this embodiment of the invention, the observation window 300 is used to directly observe the saturation state and stirring process of the fluid inside the vessel, thereby realizing the visualization monitoring and display of the core process.

[0123] like Figure 1As shown, the depressurization desorption foaming unit 400 includes: an adjustable pressure reducing component 410, a visual high-pressure reactor 420, a liquid flow regulating valve 430, and a third pressure gauge 440.

[0124] The adjustable pressure reducing component 410 is used to reduce the pressure of the stirred fluid according to predetermined pressure reducing parameters.

[0125] In this embodiment of the invention, the adjustable pressure reducing component 410 is connected to the outlet pipeline of the high-pressure dissolved gas unit 200, and is used to precisely reduce the pressure of the fluid from the high-pressure dissolved gas unit 200 according to the pressure reducing parameters determined in advance based on the on-site working conditions, so as to simulate the pressure drop process in the well or surface pipeline.

[0126] The 420 high-pressure visual reactor features an adjustable structure, providing space for the foaming process of the fluid after depressurization and allowing for visualization.

[0127] In this embodiment of the invention, the visualized high-pressure reactor 420 is the core component of the depressurization desorption foaming unit 400. Its internal structure is adjustable, providing a sudden expansion space for the depressurized fluid to simulate the environment of a ground separator. The entire foaming process is visualized through the transparent reactor body. The simulated ground separator includes a production separator and a metering separator.

[0128] In this embodiment of the invention, the structure of the visualized high-pressure reactor 420 can be adjusted according to actual working conditions. The adjustment method includes horizontal and vertical switching. Defoaming structures can be added inside the reactor to evaluate the impact of different defoaming structures on foam stability. For example, the defoaming structure is a defoaming plate.

[0129] Liquid flow regulating valve 430 is used to control the flow rate of fluid discharged.

[0130] In this embodiment of the invention, a liquid flow regulating valve 430 is installed at the liquid phase outlet of a visual high-pressure reactor 420 to control the discharge flow rate of the liquid product inside the reactor.

[0131] The third pressure gauge 440 is used to detect the real-time pressure of the visualized high-pressure reactor 420.

[0132] In this embodiment of the invention, a third pressure gauge 440 is installed on a visual high-pressure reactor 420 to detect and display the pressure data inside the reactor in real time.

[0133] like Figure 1 As shown, the depressurization desorption foaming unit 400 also includes a visualization pipe section 450.

[0134] The visualization pipe section 450 is installed on the connecting pipe section between the depressurization desorption foaming unit 400 and the high-pressure dissolved gas unit 200, and is used to visualize the fluid after depressurization treatment.

[0135] As an alternative, the visualization section 450 can also be installed at the inlet of the visualization high-pressure reactor 420.

[0136] As an alternative, the visualization section 450 can also be installed at the wellhead.

[0137] It is worth noting that the location of the visualization section 450 can be adjusted according to actual needs. It is used to determine the foam generation at different locations after the water flows from the well to the ground, so as to summarize the dynamic behavior of foam during the ground flow under different working conditions. These are the initial conditions for the ground flow.

[0138] In this embodiment of the invention, the visualization pipe section 450 is located after the adjustable pressure reducing component 410. It is a transparent connecting pipe section that connects the high-pressure dissolved gas unit 200 and the pressure reducing desorption foaming unit 400. It is used to perform preliminary visualization observation of the fluid state after pressure reduction treatment and before entering the reactor.

[0139] like Figure 1 As shown, the depressurization desorption foaming unit 400 also includes a gas flow regulating valve 460; the gas flow regulating valve 460 is used to control the flow rate of the gas discharged.

[0140] In this embodiment of the invention, a gas flow regulating valve 460 is installed at the gas phase outlet of the visualized high-pressure reactor 420 to control the discharge flow rate of the gaseous products inside the reactor. By coordinating the regulation of the liquid flow regulating valve 430 and the gas flow regulating valve 460, the dynamic working state of the separator can be simulated, and the pressure inside the reactor can be kept stable.

[0141] The depressurization desorption foaming unit 400 of this invention can achieve dynamic inflow and outflow, thereby enabling dynamic quantitative characterization of crude oil foaming characteristics under ground separator conditions based on separator data. Dynamic inflow and outflow refer to the ability to control the outflow rate of fluid from the high-temperature high-pressure reactor 210 and the visualized high-pressure reactor 420 under constant pressure, thus ensuring continuous fluid inflow into the visualized high-pressure reactor 420 while controlling the fluid level within the visualized high-temperature high-pressure reactor 210.

[0142] like Figure 1 As shown, the system also includes: a camera device 500; the camera device 500 is used to acquire real-time visual data of the foaming process of the fluid inside the high-pressure reactor 420.

[0143] In this embodiment of the invention, the camera device 500 is a high-speed camera. As an optional solution, the camera device 500 is positioned directly facing the high-pressure visualization reactor 420 to collect real-time visual data on the foaming process, foam evolution dynamics, and defoaming process of the fluid inside the reactor, providing a basis for subsequent quantitative analysis (such as foaming height, half-life, etc.).

[0144] The well-to-surface linkage CO2-driven crude oil foam performance testing system provided in this embodiment of the invention can be used to evaluate the foaming characteristics of crude oil under small pressure difference. Here, small pressure difference refers to the crude oil foaming characteristics in the sudden expansion space under small pressure difference, which can be used to quantitatively evaluate the foaming characteristics of crude oil in the sudden expansion space. The sudden expansion space mainly includes the sudden expansion space under metering separator conditions, production separator conditions, and undulating pipeline conditions.

[0145] In this embodiment of the invention, the detection method based on the well-to-surface integrated CO2-driven crude oil foam performance testing system can be determined according to different on-site oil production methods (mechanical / flowing oil production) under different operating conditions. In actual production applications, operating conditions include, but are not limited to, integrated underground and surface flowing well conditions, flowing well surface low-pressure conditions, integrated underground and surface mechanical oil production well conditions, and integrated underground and surface surface low-pressure conditions.

[0146] It is worth noting that, based on different operating conditions and basic data, the evolution of foam volume exhibits certain patterns during the actual depressurization and desorption process. A foam volume evolution model can be summarized, which can be derived by combining crude oil properties and different operating conditions. The steps of a feasible approach are as follows:

[0147] Calculate the solubility of CO2 in crude oil; generate the gas volume inside the foam under non-equilibrium conditions based on the solubility of CO2 in crude oil and the predetermined nuclear threshold pressure; construct a foam volume evolution model under non-equilibrium conditions based on the relationship between the solubility of CO2 in crude oil, the nuclear threshold pressure and the gas volume inside the foam during depressurization desorption.

[0148] Specifically, the solubility of CO2 in crude oil is first calculated. This can be done by fitting experimental data or by using the following formula:

[0149]

[0150] in, R s This refers to the solubility of CO2 in crude oil. K It is the reaction equilibrium constant; p For systemic pressure; X T The weight fraction of hydrocarbons (four-component experiment); ρ o This refers to the density of crude oil, expressed in g / cm³. 3 ; α As a correction factor; SF is the volume expansion coefficient of the CO2 and crude oil system; M T denoted as the average molecular weight of the liquid hydrocarbon.

[0151] K , αIt can be calibrated from experimental data or calculated using empirical formulas:

[0152]

[0153] Where T represents temperature.

[0154] Then, the nucleation threshold pressure (p) needs to be determined: CO2 may have different nucleation characteristics, and the nucleation threshold pressure (p) of the CO2-crude oil system needs to be determined through extensive experiments. n (The nucleation pressure is set to 0.1 when the initial pressure is below 1.5 MPa, and to 1.5 MPa when the nucleation pressure is greater than or equal to 1.5 MPa. The specific value can be determined by testing the experimental sample.)

[0155] Then, calculate the gas volume and liquid volume inside the foam under non-equilibrium conditions:

[0156] When p>p b (Bubble point pressure) Dissolved gas enters free gas, no bubbles;

[0157] When p n <p<p b The dissolved gas does not enter the free gas phase and remains in the oil, exhibiting a supersaturated state (non-equilibrium, bound gas).

[0158] When p <p n Bubble nucleation occurs, and gas enters the bubble space. Thereafter, a stable supersaturation is maintained (maintaining non-equilibrium) until the pressure drops to the target point (the gas inside the bubble is the stagnant gas, which enters the free gas after the bubble bursts). Thereafter, a stable supersaturation is maintained until the pressure drops to the target point.

[0159] The volume growth of the foam is considered as a power-law model, for pressure from p i-1 Drop to p i (p) <p n (At time), gas desorption, the theoretical amount of gas released per unit volume of dead oil (under standard conditions) is: :

[0160]

[0161] in, R s For solubility.

[0162] However, the equilibrium is not reached instantaneously; the volume of released gas increases over time (the amount of bubble nucleation is much greater than the amount of defoaming). Volume of gas released at time for:

[0163]

[0164] In the formula, For intermediate parameters, The effective time following a step change in pressure. b is the bubble growth index, representing the time required to reach equilibrium.

[0165]

[0166] Based on experimental experience, the amount of liquid carried by foam is approximately 1 / 4 of the bubble volume.

[0167] Foam volume V foam =Gas volume + Liquid volume

[0168] After reaching equilibrium, the foam volume begins to decay. Considering the exponential decay model, the change in CO2 foam volume (i.e., the volume of retained gas under pressure conditions) over time is obtained:

[0169]

[0170] in, The difference in the volume of gas released. The amount of stagnant gas.

[0171] Regarding the liquid carrying capacity of foam, it is approximately taken as 1 / 4 of the bubble volume.

[0172] Foam volume V foam =Gas volume + Liquid volume

[0173] The residual gas fraction is:

[0174]

[0175] in, The entrained gas evolution constant, The age of the bubble.

[0176] The age of the bubble is:

[0177]

[0178] The above model is a unified model combining CO2 solubility variation, foam volume growth theory, and foam decay kinetics. When different types of crude oil move through wellbores and surface gathering pipelines, the foam volume evolution can vary significantly due to pressure and temperature changes. Therefore, quantitatively evaluating foaming and foam stability through a depressurization desorption foaming unit can clarify the influence of various parameters and allow for fitting of some parameters.

[0179] The technical solution provided in this invention includes a gas supply and pressurization unit, a high-pressure dissolved gas unit, and a depressurization desorption foaming unit. The gas supply and pressurization unit is connected to the high-pressure dissolved gas unit, and the high-pressure dissolved gas unit is connected to the depressurization desorption foaming unit. The gas supply and pressurization unit is used to increase the current pressure to a predetermined saturation pressure and deliver CO2 gas to the high-pressure dissolved gas unit. The high-pressure dissolved gas unit is used to simulate underground conditions, saturating the crude oil solution with CO2 gas at a preset temperature and saturation pressure, and stirring the saturated fluid. The stirred fluid is then delivered to the depressurization desorption foaming unit through the bottom outlet. The depressurization desorption foaming unit is used to simulate surface conditions, visually displaying the foaming process of the stirred fluid to complete foam performance testing. This achieves a dynamic simulation of the entire process from underground high-pressure dissolved gas to surface depressurization separation, realistically reproducing the flow process from the wellbore to the surface, and realizing the dynamic evolution simulation of foam-containing fluid in pipelines and adjustable separators. This allows for continuous and quantitative evaluation of the foaming characteristics and foam stability of CO2-driven crude oil, providing accurate basis for surface process optimization.

[0180] It is worth noting that, Figure 1 The well-to-surface integrated CO2 flooding crude oil foam performance testing system shown is also applicable to Figure 2 or Figure 3 The method for detecting the foam performance of CO2-driven crude oil in well-to-surface linkage will not be elaborated here.

[0181] The following uses a well-to-surface integrated CO2-driven crude oil foam performance testing device as an example to illustrate the implementation process of the well-to-surface integrated CO2-driven crude oil foam performance testing method provided in this embodiment of the invention. It is understood that the executing entity of the well-to-surface integrated CO2-driven crude oil foam performance testing method provided in this embodiment of the invention includes, but is not limited to, the well-to-surface integrated CO2-driven crude oil foam performance testing device.

[0182] Figure 2 A flowchart of a well-to-surface integrated CO2 flooding crude oil foam performance testing method provided in this embodiment of the invention is shown below. Figure 2 As shown, the method includes:

[0183] Step 101: Obtain operating parameters and production well parameters.

[0184] In this embodiment of the invention, operating parameters and production well parameters are obtained through wellhead instrument data and oilfield production data. Operating parameters include, but are not limited to, oil production method, casing pressure, wellbore depth, temperature at different depths and relative density of natural gas. Production well parameters include, but are not limited to, basic parameters of production wells and dynamic parameters of production wells.

[0185] Step 102: Generate saturation pressure based on operating parameters and production well parameters.

[0186] In this embodiment of the invention, the saturation pressure varies depending on the research objective, and is mainly divided into two categories based on the research node: the initial saturation pressure with the underground and the initial saturation pressure with the surface pipeline as the research starting point. The saturation pressure with the underground research node is determined based on the bottom hole flowing pressure; the saturation pressure with the surface research node is determined based on the wellhead back pressure and temperature. However, when the starting point is the surface, the influence of underground high-pressure conditions needs to be considered, that is, the initial flow conditions of surface foam oil are affected by underground factors, and the initial conditions under different working conditions can be determined through this system.

[0187] Step 103: Inject the crude oil solution into the high-temperature and high-pressure reactor of the high-pressure dissolved gas unit, start the gas supply and pressurization unit according to the saturation pressure, and deliver CO2 gas to the high-temperature and high-pressure reactor.

[0188] In this embodiment of the invention, the crude oil solution is crude oil or an oil-water emulsion.

[0189] In this embodiment of the invention, the high-temperature, high-pressure reactor of the high-pressure dissolved gas unit for crude oil or oil-water emulsion is used to simulate underground (high-pressure inside the wellbore) conditions. Subsequently, the gas supply and pressurization unit is started according to the preset saturation pressure, and C... The gas was stably delivered into the high-temperature, high-pressure reactor, ensuring that the experiment could accurately reflect C under different moisture contents. The foaming behavior of the produced fluid.

[0190] Step 104: The crude oil solution is saturated with CO2 gas in a high-temperature and high-pressure reactor at a preset temperature and saturation pressure. The saturated fluid is stirred according to the calculated stirring parameters. The stirred fluid is then transported to the visualized high-pressure reactor of the depressurization desorption foaming unit through the bottom outlet.

[0191] In this embodiment of the invention, the stirring parameters include: the average shear rate of the wellbore pipe, the average shear rate of the fluid inside the vessel, and the power of the vessel shaft. The stirring parameters are determined based on the entropy production method.

[0192] In this embodiment of the invention, a high-temperature and high-pressure reactor is used to react crude oil solution with C at a preset temperature and saturation pressure. The gas is fully saturated. After saturation, the fluid is stirred according to the average shear rate of the wellbore or pipeline, the average shear rate of the fluid inside the reactor, and the reactor shaft power to simulate the actual flow shear process in the wellbore or pipeline. Finally, the stirred fluid is transported to the visualized high-pressure reactor of the depressurization desorption foaming unit through a dynamically adjusted drainage device connected to its bottom outlet.

[0193] In this embodiment of the invention, the high-pressure dissolved gas unit can be used as part of the depressurization desorption foaming unit. Specifically, after CO2 saturation is achieved, the automatic pressure stabilizing device controls the pressure inside the reactor to gradually decrease according to the pressure change pattern within the wellbore. The reactor is stirred at a certain speed (simulating the flow shearing process in the wellbore and pipeline). Depressurization stops when the set pressure is reached. Then, the dynamic adjustment drainage device is activated to control the visualized high-pressure reactor, allowing for quantitative evaluation of the crude oil foaming characteristics and foam stability. Saturation is considered complete when the pressure inside the high-pressure dissolved gas unit remains constant after 24 to 48 hours, with the control valve closed.

[0194] It is worth noting that the temperature setting can be adjusted according to actual needs, and this embodiment of the invention does not impose any limitations on it.

[0195] Step 105: Detect foam performance based on the foaming process inside the visualized high-pressure reactor and generate foam performance indicators.

[0196] In this embodiment of the invention, the foam performance indicators include foaming characteristic indicators and foam stability indicators. The foaming characteristic indicators include, but are not limited to, initial bubble point pressure, foaming index (DFI), maximum foaming height, and the change of foam volume over time during the foaming stage. The foam stability indicators include, but are not limited to, half-life, foam bursting index (MFCI), and the change of foam volume over time after the foam reaches its maximum volume.

[0197] In the technical solution provided by this invention, operating parameters and production well parameters are obtained; a saturation pressure is generated based on the operating parameters and production well parameters; crude oil solution is injected into the high-temperature and high-pressure reactor of the high-pressure dissolved gas unit; the gas supply and pressurization unit is started according to the saturation pressure to deliver CO2 gas to the high-temperature and high-pressure reactor; the crude oil solution and CO2 gas are saturated in the high-temperature and high-pressure reactor at a preset temperature and the saturation pressure; the saturated fluid is stirred according to the calculated stirring parameters; the stirred fluid is delivered to the visualized high-pressure reactor of the depressurization desorption foaming unit through the bottom outlet; foam performance is detected based on the foaming process in the visualized high-pressure reactor, and foam performance indicators are generated. This realizes a dynamic simulation of the entire process from underground high-pressure dissolved gas to surface depressurization separation, realistically reproducing the flow process from the wellbore to the surface, and realizing the dynamic evolution simulation of foam-containing fluid in pipelines and adjustable separators. This allows for continuous and quantitative evaluation of the foaming characteristics and foam stability of CO2-driven crude oil, providing accurate basis for surface process optimization.

[0198] Figure 3 A flowchart of another well-to-surface integrated CO2 flooding crude oil foam performance testing method provided by an embodiment of the present invention is shown below. Figure 3 As shown, the method includes:

[0199] Step 201: Obtain operating parameters and production well parameters.

[0200] In this embodiment of the invention, each step is performed by a well-to-surface linked CO2-driven crude oil foam performance testing device.

[0201] In this embodiment of the invention, the operating parameters include, but are not limited to, oil production method, casing pressure, wellbore depth, temperature at different depths and relative density of natural gas, and the production well parameters include, but are not limited to, basic parameters of the production well and dynamic parameters of the production well.

[0202] Step 202: Generate saturation pressure based on operating parameters and production well parameters.

[0203] In this embodiment of the invention, the saturation pressure at the bottom of the well is determined based on the bottom-hole flowing pressure; the saturation pressure at the surface is determined based on the wellhead back pressure and temperature. However, when the starting point is the surface, the influence of underground high-pressure conditions must be considered. That is, the initial conditions for the flow of foamed oil on the surface are affected by the underground environment, and the initial conditions under different operating conditions can be determined by this system. Specifically, the initial conditions for surface flow are: the volume of foam before the wellhead back pressure gauge under different operating conditions is summarized through experimental equipment.

[0204] Taking the saturation pressure at the Earth's subsurface as an example, the determination steps include:

[0205] Step 2021: Determine the bottom hole flowing pressure based on the differences in oil production methods.

[0206] In this embodiment of the invention, if it is a flowing well, the bottom hole flowing pressure is calculated based on the oil pressure; if it is a mechanical well, the bottom hole flowing pressure is calculated based on the fluid level calculation method. Taking mechanical well production as an example, an echo meter is used to measure the height of the dynamic fluid level in the well. L f Calculate the pressure in the air column section:

[0207]

[0208] in, p g This represents the pressure in the air column section, in MPa. p c This refers to the absolute pressure, measured in MPa. L f This refers to the height of the dynamic liquid level, in meters (m). γ g The relative density of natural gas is dimensionless. This represents the average temperature of the air column segment, in Kelvin (K). It is the compressibility factor under the average temperature and average pressure of the air column segment.

[0209] Based on the multiphase flow characteristics within the wellbore, the pressure in the oil and gas column is calculated according to the actual pump depth:

[0210]

[0211] in, p yq ρ is the pressure of the oil and gas column, MPa; ρ1 is the density of the oil and gas mixture, kg / m³. 3 It requires iterative calculation; L B The actual pump depth is in meters (m). L D The height of the moving liquid surface is in meters (m).

[0212] First, assume ρ1, then calculate... p yg Then calculate in reverse I When |ρ1- I |<0.1, iteration complete. I The calculation method is as follows:

[0213]

[0214] Where X is the calculation parameter; p c The pressure is (absolute), in MPa; p yg The pressure in the oil and gas column section is MPa. p b The saturation pressure is in MPa. I 1 and I 2 For intermediate parameters; I This is the density correction value; L C The degree of submersion is m.

[0215] Then calculate the pressure in the oil, gas, and water sections:

[0216]

[0217] In the formula, p yqw ρ is the pressure in the oil, gas, and water section; ρ2 is the density of the oil-water mixture, kg / m³. 3 g is the acceleration due to gravity, m / s² 2 ; h for; R These are gradient correction coefficients; f Δp is the water content; Δp is the pressure gradient, MPa. L z The depth at the middle of the oil layer is in meters (m); L B The depth of the pump is in meters (m). R 1 , R 2The calculation parameters are obtained by back-calculation from actual oilfield flowing pressure data, and the calculation is based on the algorithm principle of the multivariate nonlinear regression gradient acceleration method.

[0218] Finally, the calculated values ​​from each segment are summed to obtain the bottom hole flowing pressure:

[0219] p wf =p yqw + p g + p yq

[0220] In the formula, p wf Bottom hole flowing pressure; p g This refers to the pressure in the air column section; p yq This refers to the pressure in the oil and gas column section; p yqw This refers to the pressure in the oil, gas, and water sections.

[0221] Step 2022: Determine the bottom-hole flowing pressure as the saturation pressure at the research node at the bottom of the well.

[0222] Step 203: Inject the crude oil solution into the high-temperature and high-pressure reactor of the high-pressure dissolved gas unit, start the gas supply and pressurization unit according to the saturation pressure, and deliver CO2 gas to the high-temperature and high-pressure reactor.

[0223] In this embodiment of the invention, the crude oil solution is injected into the high-temperature and high-pressure reactor of the high-pressure dissolved gas unit, and the gas supply and pressurization unit is started. The working process is as follows: C A gas cylinder provides the gas source, and a gas booster device, driven by an air compressor, increases the gas pressure to the aforementioned predetermined saturation pressure. A first pressure gauge monitors the preparation process; when the pressure reaches the predetermined value, a control valve and a check valve stabilize the pressure of C, preventing backflow. The gas is delivered to the high-temperature, high-pressure reactor. At this point, the automatic pressure stabilizing device starts working, forming a closed-loop control with the second pressure gauge to ensure that the pressure inside the reactor remains constant at the saturation pressure throughout the entire saturation period.

[0224] Step 204: Based on the obtained wellbore and pipe parameters, generate the average shear rate of the wellbore and pipe according to different working conditions.

[0225] In this embodiment of the invention, the wellbore pipe parameters include, but are not limited to, the friction factor and the pipe inner diameter. Different operating conditions include power-law fluids or Newtonian fluids.

[0226] Specifically, for power-law fluids, the average shear rate of the wellbore is calculated according to the following formula:

[0227]

[0228] in, The average shear rate of the wellbore pipe; The average energy dissipation per unit volume of fluid; As a flow pattern correction factor, it requires a large amount of field data to determine the value for conditions such as bubble flow, slug flow, and stratified flow through machine learning methods, and is dimensionless; n is the flow characteristic exponent of the power-law equation, and is dimensionless; V The average fluid velocity is expressed in m / s. ρ The average density of the fluid is expressed in kg / m³. 3 ; f The friction factor is dimensionless. D This refers to the inner diameter of the pipe, in meters (m). K The consistency coefficient of a power-law fluid is expressed in Pa·s. n ; It is the acceleration due to gravity; Q For traffic; h Frictional losses of the fluid inside the pipe; L This refers to the length of the pipe. R This is the gradient correction coefficient.

[0229] It is worth noting that the average shear rate of the fluid inside the pipe can be determined based on the friction factor.

[0230] Specifically, for Newtonian fluids, n =1, K That is μ The average shear rate of the well casing is calculated according to the following formula:

[0231]

[0232] in, The average shear rate of the wellbore pipe; The average energy dissipation per unit volume of fluid; As a flow pattern correction factor, it requires a large amount of field data to determine the value for conditions such as bubble flow, slug flow, and stratified flow through machine learning methods, and is dimensionless; V The average fluid velocity is expressed in m / s. ρ The average density of the fluid is expressed in kg / m³. 3 ; f The friction factor is dimensionless. D This refers to the inner diameter of the pipe, in meters (m). K The consistency coefficient of a power-law fluid is expressed in Pa·s. n g is the acceleration due to gravity. Q For traffic; h Frictional losses of the fluid inside the pipe;L This refers to the length of the pipe. R This is the gradient correction coefficient.

[0233] Step 205: Based on the obtained parameters inside the reactor, generate the average shear rate of the fluid inside the reactor.

[0234] In this embodiment of the invention, the parameters inside the reactor include, but are not limited to, the shaft power of the stirrer and the volume of the fluid in the stirred tank. Different operating conditions include power-law fluids or Newtonian fluids.

[0235] Specifically, for Newtonian fluids, the average shear rate of the fluid inside the vessel is calculated according to the following formula:

[0236]

[0237] in, The average shear rate of the fluid inside the vessel; P Ω represents the shaft power of the agitator, in W; μ represents the dynamic viscosity of the fluid, in mPa·s. V C Let m be the volume of the fluid in the stirred tank. 3 .

[0238] Specifically, for power-law fluids, the average shear rate of the fluid inside the vessel is calculated according to the following formula:

[0239]

[0240] in, The average shear rate of the fluid inside the vessel; P Ω represents the shaft power of the agitator, in W; μ represents the dynamic viscosity of the fluid, in mPa·s. V C Let m be the volume of the fluid in the stirred tank. 3 .

[0241] The shaft power of the agitator can be calculated using the torque acting on the agitator shaft. Where P is the shaft power of the agitator, M is the torque, and N is the rotational speed; or, it can be calculated using the input power of the motor and the motor efficiency η: , where P m η is the input power of the motor, and η is the efficiency of the motor.

[0242] Step 206: Generate the reactor shaft power based on the average shear rate of the wellbore pipe.

[0243] Specifically, the average shear rate of the well shaft pipeline is determined as the reactor shaft power using the following formula.

[0244]

[0245] in, As a flow pattern correction factor, it requires a large amount of field data to determine the value for conditions such as bubble flow, slug flow, and stratified flow through machine learning methods, and is dimensionless; n is the flow characteristic exponent of the power-law equation, and is dimensionless; V The average fluid velocity is expressed in m / s. ρ The average density of the fluid is expressed in kg / m³. 3 ; f The friction factor is dimensionless. D This refers to the inner diameter of the pipe, in meters (m). K The consistency coefficient of a power-law fluid is expressed in Pa·s. n ; P This refers to the shaft power of the agitator, i.e., the reactor shaft power.

[0246] Step 207: The crude oil solution is saturated with CO2 gas in a high-temperature and high-pressure reactor at a preset temperature and saturation pressure. The saturated fluid is stirred according to the calculated stirring parameters. The stirred fluid is then transported to the visualized high-pressure reactor of the depressurization desorption foaming unit through the bottom outlet.

[0247] In this embodiment of the invention, the stirring parameters include the average shear rate of the wellbore pipe, the average shear rate of the fluid inside the vessel, and the power of the vessel shaft.

[0248] In this embodiment of the invention, under the control of the temperature control device, the temperature inside the high-temperature and high-pressure reactor is maintained at a preset value (simulating formation or wellbore temperature). Under constant temperature and saturation pressure, the crude oil solution reacts with C... The gas undergoes prolonged contact and dissolution (e.g., 24-48 hours) until it reaches or approaches equilibrium solubility under these conditions. A thermometer is used to monitor the temperature during this process in real time. After saturation, an automatic pressure stabilizing device gradually reduces the pressure inside the vessel according to the pressure variation pattern within the wellbore, while stirring is performed inside the vessel according to the stirring parameters. This is to simulate the flow shearing action experienced by fluids in underground wellbores or surface pipelines, which significantly affects the nucleation, growth, coalescence, and collapse of bubbles. Once the pressure is reduced to the set level, depressurization and stirring cease, and a dynamic regulating drainage device is activated. The fluid, having undergone underground condition simulation (high-pressure saturation + flow shearing), is then transported through the bottom outlet to the depressurization desorption foaming unit.

[0249] During transport, the fluid first undergoes further pressure reduction through an adjustable pressure-reducing component. The steps for determining the adjustable pressure-reducing component and the pressure within the visualized pipe section are as follows:

[0250] Step 2071: Obtain operating parameters, basic parameters of production wells, dynamic parameters of production wells, basic parameters of pipelines from pipeline to separator, and dynamic parameters of flow.

[0251] In this embodiment of the invention, the operating parameters include, but are not limited to, the oil production method; the basic parameters of the production well include, but are not limited to, the well depth. h Dynamic parameters of production wells include, but are not limited to, bottomhole flowing pressure. p wf Wellhead back pressure p 回 Hydraulic p 油 ,flow Q Wellhead temperature T The basic parameters of the pipeline from the separator include, but are not limited to, pipeline length. L Pipe diameter d Elevation mileage; dynamic flow parameters including but not limited to gas flow rate. Q g Liquid flow rate Q l Temperature inside the separator T Separator gas phase pressure p sep Moisture content and CO2 content in the gas.

[0252] Step 2072: Calculate the node pressure based on the operating parameters, production well basic parameters, production well dynamic parameters, pipeline to separator basic parameters, and flow dynamic parameters, and calculate the pressure gradient based on the node pressure.

[0253] In this embodiment of the invention, if the desired node is a high-pressure underground condition, the high-pressure reactor pressure drop is used to simulate the bottom-hole high-pressure condition, and the pipeline and separator are used to simulate the surface low-pressure condition. If the desired node is a surface low-pressure condition, the device temperature and pressure conditions are determined according to the actual oil production method. If it is a self-flowing oil production method, the adjustable pressure reducing component is used to simulate the pressure drop of the nozzle, and the device pipeline is used to simulate the pipeline pressure drop. However, the surface low-pressure condition needs to consider the influence of the underground high-pressure condition, and the test results under different operating conditions need to be provided by this system.

[0254] Step 2073: Store the test results under different working conditions into the database.

[0255] In this embodiment of the invention, subsequent experiments on low-pressure ground conditions select relevant results from the database based on actual working conditions.

[0256] Step 208: Determine the foaming parameters and foam parameters based on the visualized foaming process inside the high-pressure reactor.

[0257] In this embodiment of the invention, the foaming parameters include the cross-sectional area of ​​the reactor, C Saturated solubility, actual solubility C Concentration, initial liquid volume.

[0258] In this embodiment of the invention, the foam parameters include the time it takes for the foam to completely disappear and the time required for the foam volume to decrease from its maximum value to half.

[0259] Step 209: Detect foaming characteristics based on foaming parameters and generate foaming characteristic indicators.

[0260] In this embodiment of the invention, the foaming characteristic indicators include, but are not limited to, initial bubble point pressure, foaming index (DFI), maximum foaming height, and the change of foam volume over time during the foaming stage. The initial bubble point pressure is the pressure at which the first microbubbles appear; the maximum foaming height is the difference between the highest point of the foam layer and the original liquid surface, which can be obtained through observation and measurement.

[0261] Specifically, the maximum foam volume is obtained by multiplying the cross-sectional area of ​​the vessel by the maximum foaming height.

[0262] pass , for C Saturated solubility, actual solubility C The foaming index is calculated by taking the concentration, initial liquid volume, and maximum foam volume. DFI The foaming index, C Saturated solubility; For actual dissolution of C concentration; V f The maximum foam volume; V L This represents the initial liquid volume.

[0263] The change in foam volume over time during the foaming stage can be obtained by measuring the foam volume at each time point from the start time to the time point corresponding to the maximum foam volume and plotting the curve, which can be used to analyze the rate of increase.

[0264] Step 210: Perform foam stability testing based on foam parameters and generate foam stability index.

[0265] In this embodiment of the invention, foam stability indicators include, but are not limited to, half-life, foam bursting index (MFCI), and the change in foam volume over time after the foam reaches its maximum volume.

[0266] Half-life is the time required for the foam volume to decay from its maximum value to half.

[0267] pass The half-life and the time it takes for the foam to completely disappear are calculated to obtain a foam stability index. MFCI As an indicator of foam stability, t all This refers to the time it takes for the foam to completely disappear;t 1 / 2 It is the half-life.

[0268] The change in foam volume over time after the foam reaches its maximum volume can be obtained by measuring the foam volume at each time point between the time point corresponding to the maximum foam volume and the time point when the foam completely disappears, and plotting the curve. This curve can be used to analyze the rate of descent.

[0269] It is worth noting that the technical solution provided in this application provides users with a corresponding operation entry point, allowing users to choose to agree to or reject the automated decision-making result; if the user chooses to reject, the process will proceed to the expert decision-making process.

[0270] The technical solution of the well-to-surface linkage CO2-driven crude oil foam performance testing method provided in this invention involves acquiring operating parameters and production well parameters; generating a saturation pressure based on these parameters; injecting crude oil solution into a high-temperature, high-pressure reactor in a high-pressure dissolved gas unit; starting a gas supply and pressurization unit according to the saturation pressure to deliver CO2 gas to the high-temperature, high-pressure reactor; saturating the crude oil solution with CO2 gas in the high-temperature, high-pressure reactor at a preset temperature and saturation pressure; stirring the saturated fluid according to calculated stirring parameters; and delivering the stirred fluid to a visualized high-pressure reactor in a depressurization, desorption, and foaming unit through a bottom outlet; and performing foam performance testing based on the foaming process within the visualized high-pressure reactor to generate foam performance indicators. This achieves a dynamic simulation of the entire process from underground high-pressure dissolved gas to surface depressurization and separation, realistically replicating the flow process from the wellbore to the surface, and simulating the dynamic evolution of foam-containing fluid in pipelines and adjustable separators. This allows for continuous and quantitative evaluation of the foaming characteristics and foam stability of CO2-driven crude oil, providing precise data for surface process optimization.

[0271] Figure 4 This is a schematic diagram of a controller provided in an embodiment of the present invention. The controller is used to execute the above-described well-to-surface linked CO2-driven crude oil foam performance detection method, such as... Figure 4 As shown, the controller includes: an acquisition unit 11, a saturated pressure production unit 12, a pressurization unit 13, a foam reaction unit 14, and a performance detection unit 15.

[0272] The acquisition unit 11 is used to acquire operating parameters and production well parameters.

[0273] The saturation pressure production unit 12 is used to generate saturation pressure based on operating parameters and production well parameters.

[0274] The pressurization unit 13 is used to inject crude oil solution into the high-temperature and high-pressure reactor of the high-pressure dissolved gas unit. The gas supply and pressurization unit is started according to the saturation pressure to deliver CO2 gas to the high-temperature and high-pressure reactor.

[0275] The foam reaction unit 14 is used to saturate the crude oil solution with CO2 gas in a high-temperature and high-pressure reactor at a preset temperature and saturation pressure, and to stir the saturated fluid according to the calculated stirring parameters. The stirred fluid is then transported to the visualized high-pressure reactor of the depressurization desorption foaming unit through the bottom outlet.

[0276] The performance testing unit 15 is used to test the foam performance based on the foaming process in the visualized high-pressure reactor and generate foam performance indicators.

[0277] In this embodiment of the invention, the stirring parameters include: average shear rate of the wellbore pipe, average shear rate of the fluid inside the vessel, and power of the vessel shaft; the controller further includes: an average shear rate generation unit 16 for the wellbore pipe, an average shear rate generation unit 17 for the fluid inside the vessel, and a power generation unit 18 for the vessel shaft.

[0278] The wellbore pipe average shear rate generation unit 16 is used to generate the wellbore pipe average shear rate according to different working conditions and based on the obtained wellbore pipe parameters.

[0279] The average shear rate generation unit 17 for the fluid inside the reactor is used to generate the average shear rate of the fluid inside the reactor based on the acquired parameters inside the reactor.

[0280] The reactor shaft power generation unit 18 is used to generate reactor shaft power based on the average shear rate of the wellbore pipe.

[0281] In this embodiment of the invention, the reactor shaft power generation unit 18 is specifically used to... The average shear rate of the wellbore pipe is determined as the reactor shaft power, where, For flow pattern correction factor, n The flow characteristic index is the power-law equation. V The average flow velocity of the fluid. ρ The average density of the fluid. f As the friction factor, D The inner diameter of the pipe. K Let be the consistency coefficient of the power-law fluid. P This refers to the power of the reactor shaft.

[0282] In this embodiment of the invention, the foam performance indicators include foaming characteristic indicators and foam stability indicators; the performance detection unit 15 is specifically used to determine the foaming parameters and foam parameters based on the foaming process in the visualized high-pressure reactor; to perform foaming characteristic detection based on the foaming parameters and generate foaming characteristic indicators, which include the initial bubble point pressure, foaming index, maximum foaming height, and the change law of foam volume over time during the foaming stage; and to perform foam stability detection based on the foam parameters and generate foam stability indicators, which include the half-life, foam bursting index, and the change law of foam volume over time after the foam reaches its maximum volume.

[0283] In this embodiment of the invention, operating parameters and production well parameters are obtained; a saturation pressure is generated based on these parameters; crude oil solution is injected into the high-temperature, high-pressure reactor of the high-pressure dissolved gas unit; the gas supply and pressurization unit is started according to the saturation pressure to deliver CO2 gas to the high-temperature, high-pressure reactor; the crude oil solution and CO2 gas are saturated in the high-temperature, high-pressure reactor at a preset temperature and saturation pressure; the saturated fluid is stirred according to calculated stirring parameters; the stirred fluid is then delivered to the visualized high-pressure reactor of the depressurization, desorption, and foaming unit through the bottom outlet; foam performance is detected based on the foaming process in the visualized high-pressure reactor, generating foam performance indicators. This achieves a dynamic simulation of the entire process from underground high-pressure dissolved gas to surface depressurization and separation, realistically reproducing the flow process from the wellbore to the surface, and simulating the dynamic evolution of foam-containing fluid in pipelines and adjustable separators. This allows for continuous and quantitative evaluation of the foaming characteristics and stability of CO2-driven crude oil, providing precise data for surface process optimization.

[0284] The systems, devices, modules, or units described in the above embodiments can be implemented by computer chips or entities, or by products with certain functions. A typical implementation device is a computer device, specifically, a computer device can be, for example, a personal computer, a laptop computer, a cellular phone, a camera phone, a smartphone, a personal digital assistant, a media player, a navigation device, an email device, a game console, a tablet computer, a wearable device, or any combination of these devices.

[0285] This invention provides a computer device, including a memory and a processor. The memory is used to store information including program instructions, and the processor is used to control the execution of the program instructions. When the program instructions are loaded and executed by the processor, they implement the steps of the above-described well-to-surface CO2-driven crude oil foam performance testing method. For a detailed description, please refer to the above-described well-to-surface CO2-driven crude oil foam performance testing method.

[0286] The following is for reference. Figure 5 It shows a schematic diagram of the structure of a computer device 600 suitable for implementing the embodiments of this application.

[0287] like Figure 5As shown, the computer device 600 includes a central processing unit (CPU) 601, which can perform various appropriate tasks and processes based on programs stored in read-only memory (ROM) 602 or programs loaded from storage section 608 into random access memory (RAM) 603. The RAM 603 also stores various programs and data required for the operation of the computer device 600. The CPU 601, ROM 602, and RAM 603 are interconnected via a bus 604. An input / output (I / O) interface 605 is also connected to the bus 604.

[0288] The following components are connected to I / O interface 605: an input section 606 including a keyboard, mouse, etc.; an output section 607 including a cathode ray tube (CRT), liquid crystal feedback (LCD), etc., and speakers, etc.; a storage section 608 including a hard disk, etc.; and a communication section 609 including a network interface card such as a LAN card, modem, etc. The communication section 609 performs communication processing via a network such as the Internet. A drive 610 is also connected to I / O interface 605 as needed. A removable medium 611, such as a disk, optical disk, magneto-optical disk, semiconductor memory, etc., is installed on drive 610 as needed so that computer programs read from it can be installed in storage section 608 as needed.

[0289] In particular, according to embodiments of the present invention, the processes described above with reference to the flowcharts can be implemented as computer software programs. For example, embodiments of the present invention include a computer program product comprising a computer program tangibly embodied on a machine-readable medium, the computer program including program code for performing the methods shown in the flowcharts. In such embodiments, the computer program can be downloaded and installed from a network via communication section 609, and / or installed from removable medium 611.

[0290] Computer-readable media includes both permanent and non-permanent, removable and non-removable media that can store information by any method or technology. Information can be computer-readable instructions, data structures, modules of programs, or other data. Examples of computer storage media include, but are not limited to, phase-change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technologies, CD-ROM, digital versatile optical disc (DVD) or other optical storage, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other non-transferable medium that can be used to store information accessible by a computing device. As defined herein, computer-readable media does not include transient computer-readable media, such as modulated data signals and carrier waves.

[0291] For ease of description, the above devices are described separately by function as various units. Of course, in implementing this application, the functions of each unit can be implemented in one or more software and / or hardware.

[0292] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0293] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0294] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0295] It should also be noted that the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitations, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes said element.

[0296] The acquisition, storage, use, and processing of data in this application comply with relevant laws and regulations.

[0297] It should be noted that in the embodiments of this application, certain software, components, models and other existing solutions in the industry may be mentioned. These should be regarded as exemplary and are only intended to illustrate the feasibility of implementing the technical solution of this application. However, they do not mean that the solution has been or necessarily used.

[0298] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0299] This application can be described in the general context of computer-executable instructions, such as program modules, that are executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, etc., that perform a specific task or implement a specific abstract data type. This application can also be practiced in distributed computing environments where tasks are performed by remote processing devices connected via a communication network. In distributed computing environments, program modules can reside in local and remote computer storage media, including storage devices.

[0300] The various embodiments in this specification are described in a progressive manner. Similar or identical parts between embodiments can be referred to interchangeably. Each embodiment focuses on describing the differences from other embodiments. In particular, the system embodiments are basically similar to the method embodiments, so the description is relatively simple; relevant parts can be referred to the descriptions in the method embodiments.

[0301] The above description is merely an embodiment of this application and is not intended to limit this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principle of this application should be included within the scope of the claims of this application.

Claims

1. A well-ground linkage CO2 flooding crude oil foam performance detection system, characterized in that, The system includes: a gas supply and pressurization unit, a high-pressure gas dissolving unit, and a depressurization, desorption, and foaming unit; the gas supply and pressurization unit is connected to the high-pressure gas dissolving unit, and the high-pressure gas dissolving unit is connected to the depressurization, desorption, and foaming unit. The gas supply and pressurization unit is used to increase the current pressure to a predetermined saturation pressure and deliver CO2 gas to the high-pressure dissolved gas unit. The saturation pressure is the bottom hole flowing pressure determined according to the differences in oil production methods, and specifically includes: measuring the height of the dynamic fluid level in the well. L f Calculate the pressure in the air column section: ,in, p g This refers to the pressure in the air column section; p c For sleeve pressing; L f This refers to the height of the moving liquid level. γ g The relative density of natural gas; This represents the average temperature of the air column segment. This is the compressibility factor under the average temperature and average pressure of the air column section. Based on the multiphase flow characteristics within the wellbore, the pressure in the oil and gas column is calculated according to the actual pump depth: ,in, p yq ρ is the pressure of the oil and gas column; ρ1 is the density of the oil and gas mixture, which needs to be calculated iteratively. L B This is the actual pump depth; L D This refers to the height of the moving liquid level. Calculate the pressure in the oil, gas, and water sections: In the formula, p yqw ρ is the pressure in the oil-gas-water section; ρ2 is the density of the oil-water mixture; g is the acceleration due to gravity. h For well depth; R These are gradient correction coefficients; f Δp represents the water content; Δp represents the pressure gradient. L z L represents the middle depth of the oil layer. B For pump depth; R 1 , R 2 The parameters are calculated from actual oilfield flowing pressure data; d represents the differential symbol; d h For the derivative with respect to the well depth; The bottom hole flowing pressure is obtained by superimposing the pressure of the gas column section, the oil and gas column section, and the oil, gas and water section. The high-pressure dissolved gas unit is used to simulate underground conditions. Under a preset temperature and saturation pressure, the crude oil solution is saturated with CO2 gas, and the saturated fluid is stirred. The stirred fluid is then transported to the depressurization desorption foaming unit through the bottom outlet. The stirring parameters include the average shear rate of the wellbore pipe, the average shear rate of the fluid inside the reactor, and the reactor shaft power. The specific generation method of the stirring parameters includes: generating the average shear rate of the wellbore pipe based on the obtained wellbore pipe parameters according to different operating conditions; generating the average shear rate of the fluid inside the reactor based on the obtained reactor parameters; and generating the reactor shaft power based on the average shear rate of the wellbore pipe, specifically including: through... The average shear rate of the wellbore pipe is determined as the reactor shaft power, where, For flow pattern correction factor, n The flow characteristic index is the power-law equation. V The average flow velocity of the fluid. ρ The average density of the fluid. f As the friction factor, D The inner diameter of the pipe. K Let be the consistency coefficient of the power-law fluid. P Power of the reactor shaft; The depressurization and desorption foaming unit is used to simulate ground conditions and visualize the foaming process of the stirred fluid in order to complete the foam performance test. In the actual depressurization desorption process, the solubility of CO2 in crude oil is calculated; based on the solubility of CO2 in crude oil and the predetermined nuclear threshold pressure, the gas volume inside the foam under non-equilibrium conditions is generated; based on the changing relationship between the solubility of CO2 in crude oil, the nuclear threshold pressure, and the gas volume inside the foam during depressurization desorption, a foam volume evolution model under non-equilibrium conditions is constructed: ,in, This represents the change in CO2 foam volume over time. The difference in the volume of gas released. For the fraction of retained gas, SF Let be the volumetric expansion coefficient of the CO2 and crude oil system, and p be the system pressure.

2. The well-to-surface integrated CO2 flooding crude oil foam performance testing system according to claim 1, characterized in that, The gas supply and pressurization unit includes a CO2 cylinder, a first one-way valve, a gas booster device, a first pressure gauge, and a second one-way valve. The CO2 cylinder is used to store CO2 gas, and the unidirectional delivery of CO2 gas is controlled by a first one-way valve. The gas booster device is used to increase the current pressure to the saturation pressure; The first pressure gauge is used to measure and display the current pressure. If the current pressure reaches the saturation pressure, the unidirectional delivery of CO2 gas is controlled by the second one-way valve.

3. The well-to-surface integrated CO2 flooding crude oil foam performance testing system according to claim 2, characterized in that, The air supply and pressurization unit also includes: an air compressor; The air compressor is used to provide a power source for the gas booster device.

4. The well-to-surface integrated CO2 flooding crude oil foam performance testing system according to claim 1, characterized in that, The gas supply and pressurization unit also includes: a control valve; The control valve is used to control the delivery of CO2 gas from the gas supply and pressurization unit to the high-pressure dissolved gas unit.

5. The well-to-surface integrated CO2 flooding crude oil foam performance testing system according to claim 1, characterized in that, The high-pressure dissolved gas unit includes: a high-temperature and high-pressure reactor, a second pressure gauge, a thermometer, an automatic pressure stabilizing device, a temperature control device, and a dynamic regulating drainage device; The high-temperature and high-pressure reactor provides space for the crude oil solution and CO2 gas to be saturated, and stirs the saturated fluid. The second pressure gauge is used to detect the real-time pressure of the high-temperature and high-pressure reactor; The thermometer is used to detect the real-time temperature of the high-temperature and high-pressure reactor; The automatic pressure stabilizing device is used to control the pressure of the high-temperature and high-pressure reactor. The temperature control device is used to control the temperature of the high-temperature and high-pressure reactor. The dynamic adjustment drainage device is used to control the flow of the stirred fluid through the bottom outlet of the high-temperature and high-pressure reactor to the depressurization desorption foaming unit.

6. The well-to-surface integrated CO2 flooding crude oil foam performance testing system according to claim 5, characterized in that, The high-temperature and high-pressure reactor includes: a speed sensor, a torque sensor, a stirrer, and an observation window; The torque sensor is used to obtain the torque of the stirrer; The speed sensor is used to obtain the speed of the stirrer; The agitator is used to agitate the saturated fluid according to the calculated agitation parameters, which are determined based on the agitator's torque, rotation speed, acquired wellbore pipe parameters, and reactor internal parameters. The observation window is used to visualize the stirring process of the saturated fluid.

7. The well-to-surface integrated CO2 flooding crude oil foam performance testing system according to claim 1, characterized in that, The depressurization desorption foaming unit includes: an adjustable pressure reducing component, a visual high-pressure reactor, a liquid flow regulating valve, and a third pressure gauge; The adjustable pressure reduction component is used to reduce the pressure of the stirred fluid according to predetermined pressure reduction parameters. The visualized high-pressure reactor has an adjustable structure, providing space for the foaming process of the fluid after depressurization and allowing for visualization. The visualized high-pressure reactor provides a sudden expansion space for the fluid after depressurization, simulating a ground separator environment. The simulated ground separator includes a production separator and a metering separator. The liquid flow regulating valve is used to control the flow rate of the fluid discharged; The third pressure gauge is used to detect the real-time pressure of the visualized high-pressure reactor.

8. The well-to-surface integrated CO2 flooding crude oil foam performance testing system according to claim 7, characterized in that, The depressurization desorption foaming unit also includes: a visualized pipe section; The visualization pipe section is set on the connecting pipe section between the pressure reduction desorption foaming unit and the high-pressure dissolved gas unit, or at the inlet of the visualization high-pressure reactor, or at the wellhead position; The visualization pipe section is used to visualize the foaming process at different locations as the fluid flows from the wellbore to the surface after decompression treatment.

9. The well-to-surface integrated CO2 flooding crude oil foam performance testing system according to claim 7, characterized in that, The pressure-reducing desorption foaming unit also includes: a gas flow regulating valve; The gas flow regulating valve is used to control the flow rate of the discharged gas.

10. The well-to-surface integrated CO2 flooding crude oil foam performance testing system according to claim 7, characterized in that, The system also includes: a camera device; The camera device is used to collect real-time visual data of the foaming process of fluid inside the high-pressure reactor.

11. A method for testing the foam performance of CO2-assisted crude oil in a well-to-surface integrated manner, characterized in that, The method applied to the well-to-surface CO2-assisted crude oil foam performance testing system according to any one of claims 1 to 10, the method comprising: Obtain operating parameters and production well parameters; The bottom hole flowing pressure, determined based on differences in oil production methods, is defined as the saturation pressure, specifically including: Measuring the height of the dynamic fluid level in the well L f Calculate the pressure in the air column section: ,in, p g This refers to the pressure in the air column section; p c For sleeve pressing; L f This refers to the height of the moving liquid level. γ g The relative density of natural gas; This represents the average temperature of the air column segment. This is the compressibility factor under the average temperature and average pressure of the air column section. Based on the multiphase flow characteristics within the wellbore, the pressure in the oil and gas column is calculated according to the actual pump depth: ,in, p yq ρ is the pressure of the oil and gas column; ρ1 is the density of the oil and gas mixture, which needs to be calculated iteratively. L B This is the actual pump depth; L D This refers to the height of the moving liquid level. Calculate the pressure in the oil, gas, and water sections: In the formula, p yqw ρ is the pressure in the oil-gas-water section; ρ2 is the density of the oil-water mixture; g is the acceleration due to gravity. h For well depth; R These are gradient correction coefficients; f Δp represents the water content; Δp represents the pressure gradient. L z L represents the middle depth of the oil layer. B For pump depth; R 1 , R 2 The parameters are calculated from actual oilfield flowing pressure data; d represents the differential symbol; d h For the derivative with respect to the well depth; The bottom hole flowing pressure is obtained by superimposing the pressure of the gas column section, the oil and gas column section, and the oil, gas and water section. The crude oil solution is injected into the high-temperature and high-pressure reactor of the high-pressure dissolved gas unit, and the gas supply and pressurization unit is started according to the saturation pressure to deliver CO2 gas to the high-temperature and high-pressure reactor. The crude oil solution is saturated with CO2 gas in the high-temperature and high-pressure reactor at a preset temperature and saturation pressure. The saturated fluid is stirred according to the calculated stirring parameters. The stirred fluid is then transported to the visualized high-pressure reactor of the depressurization desorption foaming unit through the bottom outlet. Foam performance is tested based on the visualized foaming process inside the high-pressure reactor, and foam performance indicators are generated. The stirring parameters include: average shear rate of the wellbore pipe, average shear rate of the fluid inside the vessel, and vessel shaft power; the method further includes: Based on different working conditions and the obtained wellbore and pipeline parameters, the average shear rate of the wellbore and pipeline is generated. Based on the obtained parameters inside the reactor, the average shear rate of the fluid inside the reactor is generated. Based on the average shear rate of the wellbore pipe, the reactor shaft power is generated, specifically including: pass The average shear rate of the wellbore pipe is determined as the reactor shaft power, where, For flow pattern correction factor, n The flow characteristic index is the power-law equation. V The average flow velocity of the fluid. ρ The average density of the fluid. f As the friction factor, D The inner diameter of the pipe. K Let be the consistency coefficient of the power-law fluid. P Power of the reactor shaft; The method further includes: Calculate the solubility of CO2 in crude oil; Based on the solubility of CO2 in crude oil and the predetermined nuclear threshold pressure, the volume of gas inside the foam under non-equilibrium conditions is generated. Based on the relationship between the solubility of CO2 in crude oil, the nuclear threshold pressure, and the gas volume within the foam during depressurization desorption, a non-equilibrium foam volume evolution model is constructed: ,in, This represents the change in CO2 foam volume over time. The difference in the volume of gas released. For the fraction of retained gas, SF Let be the volumetric expansion coefficient of the CO2 and crude oil system, and p be the system pressure.

12. The well-to-surface integrated CO2 flooding crude oil foam performance testing method according to claim 11, characterized in that, The foam performance indicators include foaming characteristic indicators and foam stability indicators; The process of detecting foam performance based on the visualized foaming process within the high-pressure reactor and generating foam performance indicators includes: Based on the visualized foaming process inside the high-pressure reactor, the foaming parameters and foam parameters are determined. Based on the foaming parameters, foaming characteristics are tested to generate foaming characteristic indicators, including initial bubble point pressure, foaming index, maximum foaming height, and the change law of foam volume over time during the foaming stage. Based on the foam parameters, foam stability is tested to generate foam stability indices, which include half-life, foam bursting index, and the change in foam volume over time after the foam reaches its maximum volume.

13. A controller, characterized in that, The controller includes: Acquisition unit, used to acquire operating condition parameters and production well parameters; The saturation pressure production unit is used to determine the bottom hole flowing pressure as the saturation pressure based on the differences in oil production methods. The pressurization unit is used to inject crude oil solution into the high-temperature and high-pressure reactor of the high-pressure dissolved gas unit. The gas supply and pressurization unit is started according to the saturation pressure to deliver CO2 gas to the high-temperature and high-pressure reactor. The foam reaction unit is used to saturate crude oil solution with CO2 gas in a high-temperature and high-pressure reactor at a preset temperature and saturation pressure, and to stir the saturated fluid according to the calculated stirring parameters. The stirred fluid is then transported to the visualized high-pressure reactor of the depressurization desorption foaming unit through the bottom outlet. The performance testing unit is used to test the foam performance based on the foaming process inside the visualized high-pressure reactor and generate foam performance indicators. The saturated pressure production unit is specifically used to measure the height of the dynamic fluid level in the well. L f Calculate the pressure in the air column section: ,in, p g This refers to the pressure in the air column section; p c For sleeve pressing; L f This refers to the height of the moving liquid level. γ g The relative density of natural gas; This represents the average temperature of the air column segment. This is the compressibility factor under the average temperature and average pressure of the air column section. Based on the multiphase flow characteristics within the wellbore, the pressure in the oil and gas column is calculated according to the actual pump depth: ,in, p yq ρ is the pressure of the oil and gas column; ρ1 is the density of the oil and gas mixture, which needs to be calculated iteratively. L B This is the actual pump depth; L D This refers to the height of the moving liquid level. Calculate the pressure in the oil, gas, and water sections: In the formula, p yqw ρ is the pressure in the oil-gas-water section; ρ2 is the density of the oil-water mixture; g is the acceleration due to gravity. h For well depth; R These are gradient correction coefficients; f Δp represents the water content; Δp represents the pressure gradient. L z L represents the middle depth of the oil layer. B For pump depth; R 1 , R 2 The parameters are calculated from actual oilfield flowing pressure data; d represents the differential symbol; d h For the derivative with respect to the well depth; The bottom hole flowing pressure is obtained by superimposing the pressure of the gas column section, the oil and gas column section, and the oil, gas and water section. The stirring parameters include: average shear rate of the wellbore and pipeline, average shear rate of the fluid inside the vessel, and power of the vessel shaft; the controller also includes: an average shear rate generation unit for the wellbore and pipeline, an average shear rate generation unit for the fluid inside the vessel, and a power generation unit for the vessel shaft. The wellbore pipeline average shear rate generation unit is used to generate the wellbore pipeline average shear rate according to different working conditions and based on the obtained wellbore pipeline parameters. The average shear rate generation unit for the fluid inside the reactor is used to generate the average shear rate of the fluid inside the reactor based on the obtained parameters inside the reactor. The reactor shaft power generation unit is used to generate reactor shaft power based on the average shear rate of the wellbore pipe. The reactor shaft power generation unit is specifically used for... The average shear rate of the wellbore pipe is determined as the reactor shaft power, where, For flow pattern correction factor, n The flow characteristic index is the power-law equation. V The average flow velocity of the fluid. ρ The average density of the fluid. f As the friction factor, D The inner diameter of the pipe. K Let be the consistency coefficient of the power-law fluid. P Power of the reactor shaft; The controller also includes: a foam volume evolution model construction unit for non-equilibrium states; The non-equilibrium foam volume evolution model building unit is used to calculate the solubility of CO2 in crude oil; based on the solubility of CO2 in crude oil and a predetermined core threshold pressure, it generates the gas volume inside the foam under non-equilibrium conditions; based on the changing relationship between the solubility of CO2 in crude oil, the core threshold pressure, and the gas volume inside the foam during depressurization desorption, it constructs a non-equilibrium foam volume evolution model. ,in, This represents the change in CO2 foam volume over time. The difference in the volume of gas released. For the fraction of retained gas, SF Let be the volumetric expansion coefficient of the CO2 and crude oil system, and p be the system pressure.

14. A computer-readable medium having a computer program stored thereon, characterized in that, When executed by the processor, the program implements the well-to-surface linkage CO2 flooding crude oil foam performance detection method according to any one of claims 11 to 12.

15. A computer device comprising a memory and a processor, the memory for storing information including program instructions, and the processor for controlling the execution of the program instructions, characterized in that, When the program instructions are loaded and executed by the processor, the well-to-surface linkage CO2 flooding crude oil foam performance testing method according to any one of claims 11 to 12 is implemented.

16. A computer program product comprising a computer program / instructions, characterized in that, When the computer program / instruction is executed by the processor, it implements the well-to-surface linkage CO2 flooding crude oil foam performance testing method according to any one of claims 11 to 12.

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