Oil extraction experiment device

Abstract

The invention provides an oil extraction experiment device which is characterized in that a supply subsystem comprises a liquid injection unit and a gas injection unit, and the gas injection unit is connected with the liquid injection unit through a pipeline; the input end of the first subsystem and the input end of the second subsystem are each provided with a liquid pipeline communicating with the liquid injection unit and a gas pipeline communicating with the gas injection unit, and the liquid pipeline communicating with the first subsystem and the gas pipeline communicating with the second subsystem intersect with the gas pipeline and the liquid pipeline communicating with the second subsystem in a one-to-one correspondence mode. The output end of the first subsystem and the output end of the second subsystem are connected with the data subsystem through pipelines. According to the oil extraction experimental device, the supply subsystem supplies various fluids with different components through pipeline crossing, the efficiency of supplying multi-element thermal fluids and experimental fluids with any components is achieved by independently controlling injected gas and liquid, and the temperature requirement and the multifunctional requirement of heavy oil field simulation are met.

Description

Technical Field

[0001] This invention belongs to the field of oil production experiment technology, and specifically relates to an oil production experiment device. Background Technology

[0002] In the process of developing heavy oil resources, in order to reveal the reaction mechanism of heavy oil and provide theoretical parameters and suggestions for the preparation of field test schemes, it is common to invent a physical simulation device for heavy oil thermal recovery and to conduct in-depth research on the laws and effects of thermal recovery such as multi-media assisted and gas injection mining in heavy oil reservoirs.

[0003] However, some heavy oil reservoirs are already in the late stages of development characterized by high temperature, high humidity, and low pressure. The strong heterogeneity of these reservoirs directly leads to more complex reservoir engineering parameters and injection-production process parameters (including temperature, flow rate, and pressure) during simulation experiments. Extensive research has revealed that existing physical simulation devices are functionally limited and cannot select different production model experiments based on varying needs. Furthermore, the fluid injection in the injection-production process is singular and cannot meet the requirements of multi-fluid injection-production processes. Overall, currently, there are no experimental physical simulation devices suitable for strongly heterogeneous conglomerate heavy oil reservoirs, either domestically or internationally. Summary of the Invention

[0004] To address the above problems, this invention proposes an oil production experimental device, comprising: a supply subsystem, a first subsystem, a second subsystem, and a data subsystem;

[0005] The supply subsystem includes a liquid injection unit and a gas injection unit, which are connected by pipelines.

[0006] The input ends of both the first subsystem and the second subsystem are equipped with liquid pipelines that connect to the liquid injection unit and gas pipelines that connect to the gas injection unit. The liquid pipelines and gas pipelines connected to the first subsystem intersect with the gas pipelines and liquid pipelines connected to the second subsystem, respectively.

[0007] The outputs of both the first and second subsystems are connected to the data subsystem via pipelines.

[0008] Furthermore, the liquid injection unit includes: a liquid injection pump, several intermediate buffer containers, and a fluid preheating module connected in sequence;

[0009] The other end of the fluid preheating module is connected to the first subsystem and the second subsystem via a liquid pipeline.

[0010] Furthermore, the liquid injection pump includes a variable speed injection pump and a constant speed and constant pressure pump, which are connected to several intermediate buffer containers via a fifth pipeline.

[0011] Furthermore, the gas injection unit includes: an air compressor, a gas booster module, a gas storage pipe, a pressure regulator, a flow controller, and a gas heat exchanger connected in sequence;

[0012] The gas booster module is connected to the high-pressure gas distribution module via pipeline;

[0013] The gas heat exchanger is connected to the first subsystem and the second subsystem respectively via gas pipelines;

[0014] The flow controller is connected to the fifth pipeline via a conduit.

[0015] Furthermore, the high-pressure gas distribution module includes a transfer mixing cylinder and several gas cylinders containing different gases;

[0016] Several gas cylinders are connected to one end of a transfer mixing cylinder via pipelines;

[0017] The other end of the transfer mixing cylinder is connected to the gas pressurization module via a pipeline.

[0018] Furthermore, the first subsystem adopts a thermal recovery subsystem, and the second subsystem adopts a pyrolysis subsystem.

[0019] Furthermore, the model of the first subsystem is equipped with a heating and insulation device, an ignition device, and a hydraulic tracking device;

[0020] The heating device is used to heat the cavity of the first subsystem;

[0021] The ignition simulation device is used to simulate fire-driven mining experiments;

[0022] The hydraulic tracking device is used to regulate the internal pressure of the first subsystem.

[0023] Furthermore, the model of the first subsystem includes several horizontal and vertical wells.

[0024] Furthermore, the data subsystem includes two output measurement units and two data acquisition units;

[0025] Two data acquisition units are installed on the first subsystem and the second subsystem, respectively;

[0026] The two output metering units are connected to the output terminals of the first and second subsystems respectively via pipelines.

[0027] Furthermore, the data subsystem also includes a vacuum unit, a back pressure control unit, a primary separation module, and a secondary separation module;

[0028] The two-stage separation module has an input terminal and a first output terminal;

[0029] One end of the back pressure control unit is connected to the first subsystem via a pipeline, and the other end of the back pressure control unit is connected to the input end of the secondary separation module via a pipeline. The first output end of the secondary separation module is connected to the output metering unit via a pipeline.

[0030] One end of the primary separation module is connected to the second subsystem via a pipeline, the other end of the primary separation module is connected to one end of the vacuum unit via a pipeline, the other end of the vacuum unit is connected to the input end of the secondary separation module via a pipeline, and the first output end of the secondary separation module is connected to the output metering unit via a pipeline.

[0031] Furthermore, the data subsystem also includes a cooling module and an exhaust gas collection module. The secondary separation module also has a second output terminal. One end of the cooling module is connected to the primary separation module, and the other end of the cooling module is connected to the second subsystem. The exhaust gas collection module is connected to the second output terminal of the secondary separation module.

[0032] The beneficial effects of this invention are as follows:

[0033] 1. The oil production experimental device of this application enables the supply subsystem to supply fluids with multiple different compositions through pipeline intersection. By controlling the injected gas and liquid separately, the overall control of the component content and corresponding temperature and pressure of the injected fluid is directly realized. It has the supply efficiency of multi-component thermal fluids and experimental fluids of arbitrary composition, which greatly improves the accuracy of the injected fluid parameters, expands the variation range of the injected fluid parameters, and ensures the accuracy of subsequent test results and simulation effects, thereby meeting the temperature requirements and multi-functional needs of heavy oil field simulation.

[0034] 2. By merging the first and second subsystems into the same simulation device, the dual functions of steam extraction and fire-driven extraction can be met. Different modules can be selected to carry out different mining model experiments according to different needs, satisfying the simulation requirements of "one injection and one extraction" or "one injection and multiple extractions".

[0035] 3. By using several horizontal and vertical wells, the experimental requirements of multiple well groups are met, thereby simulating the injection volume of injection wells and the oil, water, and gas production of production wells. This allows for the study of the impact of reservoir engineering parameters and injection-production process parameters on the production effect under different development methods, providing reliable design parameters for the design of pilot field tests.

[0036] Other features and advantages of the invention will be set forth in the following description, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures pointed out in the description and the drawings. Attached Figure Description

[0037] 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 some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0038] Figure 1 A schematic diagram of the oil production experimental device in an embodiment of the present invention is shown.

[0039] In the diagram, the components are: 1. First subsystem; 2. Second subsystem; 3. Intermediate buffer container; 4. Fluid preheating module; 5. Variable speed injection pump; 6. Constant speed and constant pressure pump; 7. Air compressor; 8. Gas booster module; 9. Gas storage pipe; 10. Pressure regulator; 11. Flow controller; 12. High-pressure gas distribution module; 121. Gas cylinder; 122. Transfer mixing cylinder; 13. Gas heat exchanger; 14. Output metering unit; 15. Data acquisition unit; 16. Back pressure control unit; 17. Primary separation module; 18. Secondary separation module; 19. Refrigeration module; 20. Exhaust gas collection module; 21. First pipeline; 22. Second pipeline; 23. Third pipeline; 24. Fourth pipeline; 25. Fifth pipeline. Detailed Implementation

[0040] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, 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, 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.

[0041] This invention provides an oil production experimental device. Figure 1 A schematic diagram of the oil production experimental device in an embodiment of the present invention is shown. Figure 1 The oil production experimental device includes: a supply subsystem, a first subsystem 1, a second subsystem 2, and a data subsystem;

[0042] The supply subsystem includes a liquid injection unit and a gas injection unit, which are connected by pipelines.

[0043] Both the first subsystem 1 and the second subsystem 2 have input terminals equipped with liquid pipelines connecting to the liquid injection unit and gas pipelines connecting to the gas injection unit. Furthermore, the liquid pipelines and gas pipelines connected to the first subsystem 1 intersect one-to-one with the gas pipelines and liquid pipelines connected to the second subsystem 2. Figure 1In this application, the liquid pipeline includes a first pipeline 21 and a second pipeline 22. The liquid injection units are connected to the input terminals of the first subsystem 1 and the second subsystem 2 respectively through the first pipeline 21 and the second pipeline 22. The gas pipeline includes a third pipeline 23 and a fourth pipeline 24. The gas injection units are connected to the input terminals of the first subsystem 1 and the second subsystem 2 respectively through the third pipeline 23 and the fourth pipeline 24. The third pipeline 23 intersects with the first pipeline 21, and the second pipeline 22 intersects with the fourth pipeline 24. One-way valves are installed on the first pipeline 21, the second pipeline 22, the third pipeline 23, and the fourth pipeline 24.

[0044] The outputs of both the first subsystem 1 and the second subsystem 2 are connected to the data subsystem via pipelines.

[0045] In this application, the pipeline intersection enables the supply subsystem to supply fluids with multiple different compositions. This method also enables three relatively independent flow channels: single gas, single liquid, and gas-liquid mixture. By controlling the injected gas and liquid separately, the overall control of the injected fluid component content and corresponding temperature and pressure is directly achieved. It has the supply efficiency of multi-component thermal fluids and experimental fluids of arbitrary composition, which greatly improves the accuracy of the injected fluid parameters, expands the variation range of the injected fluid parameters, and ensures the accuracy of subsequent test results and simulation effects, thereby meeting the temperature requirements and multifunctional needs of heavy oil field simulation.

[0046] In the embodiments of this application, taking the first subsystem 1 as a thermal recovery subsystem and the second subsystem 2 as a pyrolysis subsystem as an example, by merging the first subsystem 1 and the second subsystem 2 into the same simulation device, the dual functions of steam extraction and fire-driven extraction can be met. Different extraction model experiments can be carried out according to different needs, meeting the simulation requirements of "one injection and one production" or "one injection and multiple production", and simulating the injection volume of injection wells and the oil, water and gas production of production wells. It can carry out research on the influence of reservoir engineering parameters and injection and production process parameters on the extraction effect under different development methods, and provide reliable design parameters for entering the field pilot test design.

[0047] In terms of regulating the injected liquid, the system consists of a liquid injection pump, several intermediate buffer containers 3, and a fluid preheating module 4 connected in sequence.

[0048] The other end of the fluid preheating module 4 is connected to the first subsystem 1 and the second subsystem 2 via a liquid pipeline.

[0049] The intermediate buffer container 3 provides storage space for the liquid input by the liquid injection pump and the gas-liquid mixture jointly input by the liquid injection pump and the gas injection unit. Specifically, it stores formation-saturated crude oil and mixtures of crude oil and gas, and provides a buffer zone for the liquid or gas-liquid mixture, controlling its flow rate to improve the stability of the flow process. All components of the intermediate buffer container 3 are made of titanium alloy and equipped with an on / off control module, meeting the requirements of operating environments ranging from 0℃ to 80℃, thus accommodating different temperature variations in the environment. For example, the intermediate buffer container 3 has an internal volume of 5000ml and a pressure of 16MPa.

[0050] The fluid preheating module 4 is used to preheat the injected fluid. For example, the internal temperature control range for fluid preheating in the fluid preheater module 4 is 0℃ to 300℃, which is a wide temperature control range to meet the temperature requirements of heavy oil field simulation. Correspondingly, the steam discharge is 9L / h, the temperature control accuracy is ±0.5℃, and the heating power is 18KW.

[0051] Correspondingly, the liquid injection pump includes a variable speed injection pump 5 and a constant speed and constant pressure pump 6. According to actual use, the variable speed injection pump 5 and the constant speed and constant pressure pump 6 are connected to several intermediate buffer containers 3 through the fifth pipeline 25. By combining the variable speed injection pump 5 and the constant speed and constant pressure pump 6, the liquid injection pump has the characteristics of variable speed, high pressure, high precision and long-term operation. In practice, it can achieve continuous operation for 1000 hours, which greatly improves the stability of liquid output and can adjust the discharge limit to 0.01-150ml / min, control the flow accuracy within ±5%, and meet the working environment with a maximum working pressure of 10MPa.

[0052] In terms of gas injection control, the gas injection unit includes: an air compressor 7, a gas booster module 8, a gas storage pipe 9, a pressure regulator 10, a flow controller 11, and a gas heat exchanger 13 connected in sequence to form a unidirectional pipeline.

[0053] The high-pressure gas distribution module 12 is located on one side of the gas boosting module 8, and the high-pressure gas distribution module 12 is connected to the gas boosting module 8 through a pipeline. The high-pressure gas distribution module 12 serves as the unit for gas output. By delivering gas to the gas boosting module 8, it pressurizes the gas in a timely manner while inputting the gas into the pipeline, ensuring the degree of gas mixing.

[0054] The gas heat exchanger 13 is connected to the first subsystem 1 and the second subsystem 2 respectively through the third pipeline 23 and the fourth pipeline 24. Based on the gas output controlled by the flow controller 11, the gas is heated and the gas temperature is adjusted accordingly to meet the temperature requirements of the heavy oil field simulation.

[0055] The flow controller 11 is also connected to the fifth pipeline 25 between the liquid injection pump and the intermediate buffer container 3 via a pipeline to control the gas output to ensure the fluid ratio formed by mixing.

[0056] In this embodiment, the flow controller 11 is used to accurately measure and control the amount of gas injected, and the air compressor 7 is used to compress the injected gas. In actual use, the full scale of the flow controller 11 is 2000 ml / min, and the maximum test pressure is 5 MPa; the corresponding air compressor 7 has a rated pressure of 1 MPa, a volumetric flow rate of 0.465 m3 / min, and an operating noise of less than 60 dB; the internal capacity of the gas storage tube 9 is 100 L; the maximum inlet pressure of the pressure regulator 10 is 3000 psi, the outlet pressure is 50-1500 psi, and the pressure regulation accuracy is 50 psi.

[0057] Secondly, although they are all marked in the figure, corresponding auxiliary modules, such as low-pressure gas storage tanks and safety systems, can be added to the gas injection unit to further assist in flow control and safety control during the gas injection process.

[0058] In this embodiment, the high-pressure gas distribution module 12 includes a transfer mixing cylinder 122 and several gas delivery cylinders 121 containing different gases. In order to meet the simulation of the field environment in this application, this embodiment is provided with three gas delivery cylinders 121, which are respectively filled with nitrogen, oxygen and hydrocarbon gas.

[0059] Several gas cylinders 121 are connected to one end of a transfer mixing cylinder 122 via pipelines;

[0060] The other end of the intermediate mixing cylinder 122 is connected to the gas booster module 8 via a pipeline.

[0061] To further simulate the actual on-site environment, several independent gas cylinders 121 are used to load different types of high-pressure gases, and a transfer mixing cylinder 122 is used to provide space for mixing the gases output from different gas cylinders 121, which facilitates subsequent compression and mixing of various gases.

[0062] In addition, the transfer mixing cylinder 122 is also equipped with a pipeline for external connection, and a one-way valve is also installed on the pipeline. During the test, air or carbon dioxide can be unidirectionally supplied to the transfer mixing cylinder 122 through the pipeline to meet the input of temporary gas mixing operations.

[0063] In the above-mentioned device, the first subsystem 1 adopts a thermal recovery subsystem, and the second subsystem 2 adopts a pyrolysis subsystem. The first subsystem 1 adopts a φ1000×700mm specification, and the internal temperature-resistant reactor has a diameter of 200×500mm. The working temperature is room temperature 0℃~400℃, and the maximum working pressure is 6MPa. The inner wall of the model is equipped with a fire-resistant insulation layer. The model is equipped with 200 temperature sensors and 10 temperature fields arranged at equal intervals to ensure effective monitoring of the temperature field and pressure field inside the model during the test, so that the system operating parameters meet the test requirements. The model of the first subsystem 1 is equipped with a heating and heat preservation device, an ignition device, and a hydraulic tracking device.

[0064] The heating device is used to heat the cavity of the first subsystem 1;

[0065] The ignition simulation device is used to simulate fire-driven mining experiments;

[0066] The hydraulic tracking device is used to regulate the internal pressure of the first subsystem 1.

[0067] In addition, the model of the first subsystem 1 includes several horizontal and vertical wells;

[0068] For example, five pairs of horizontal wells and 20 vertical wells are set up in the model of the first subsystem 1.

[0069] From a model structure perspective, selecting two pairs of horizontal well edges in the lower part can be used to simulate gravity drainage experiments in dual horizontal wells; selecting one vertical well and one horizontal well can be used to simulate combined vertical and horizontal well drainage experiments; selecting multiple vertical wells can be used to simulate injection, linear well network drive, and oil production experiments; in terms of well network, setting several vertical wells can be used to simulate experiments in five-point well networks, nine-point well networks, and circular well networks, meeting the experimental requirements of multi-well groups. Furthermore, it can simulate the injection volume of injection wells and the oil, water, and gas production of production wells, and conduct research on the impact of reservoir engineering parameters and injection-production process parameters on production effects under different development methods, providing reliable design parameters for entering the field pilot test design.

[0070] It should be further explained that the model of the first subsystem 1 in this application adopts a specification of φ1000×700mm. This specification of model can no longer be operated in the existing conventional pressure chamber. Therefore, by adding a heating and heat preservation device, a hydraulic tracking device and a fire-resistant heat insulation layer, the temperature and pressure of the first subsystem 1 are controlled, so that the model of the first subsystem 1 does not need to be built into the pressure chamber like the traditional simulation model. The volume of the model of the first subsystem 1 is not limited by the volume of the pressure chamber. During the experiment, when the model is filled, models with different permeability can be obtained directly by filling quartz sand or clay of different particle sizes, and the volume requirements of each component are met to realize the simulation of heterogeneity.

[0071] The second subsystem 2 adopts a columnar structure with dimensions of φ200×500mm, an operating temperature of 0℃~1200℃, and a maximum operating pressure of 20MPa. It provides a high-temperature, sealed, and insulated environment to simulate steam extraction experiments.

[0072] The data subsystem includes two output measurement units 14 and two data acquisition units 15;

[0073] Two data acquisition units 15 are respectively installed on the first subsystem 1 and the second subsystem 2. The data acquisition units 15 monitor the temperature and pressure in the first subsystem 1 and the second subsystem 2 in real time, and also achieve early warning function through the preset temperature upper limit and pressure upper limit.

[0074] The two output metering units 14 are respectively connected to the output terminals of the first subsystem 1 and the second subsystem 2 through pipelines.

[0075] In this embodiment, the production metering unit 14 performs online measurement of the heavy oil extraction process to obtain the real-time extracted weight. In actual use, the range of the production metering unit 14 can be set to 2200g and the accuracy to 0.1g to meet the accuracy requirements of the measurement value.

[0076] Specifically, the data subsystem also includes a vacuum unit, a back pressure control unit 16, a primary separation module 17, and a secondary separation module 18;

[0077] The secondary separation module 18 has an input terminal, a first output terminal, and a second output terminal;

[0078] One end of the back pressure control unit 16 is connected to the first subsystem 1 via a pipeline, and the other end of the back pressure control unit 16 is connected to the input end of the secondary separation module 18 via a pipeline. The first output end of the secondary separation module 18 is connected to the production metering unit 14 via a pipeline. The back pressure control unit 16 further regulates the pressure in the pipeline to improve the efficiency of heavy oil extraction.

[0079] One end of the primary separation module 17 is connected to the second subsystem 2 via a pipeline, and the other end of the primary separation module 17 is connected to one end of the vacuum unit via a pipeline. The other end of the vacuum unit is connected to the input end of the secondary separation module 18 via a pipeline. The first output end of the secondary separation module 18 is connected to the output metering unit 14 via a pipeline. Through two separations, the operational requirements for separating fluids in the experiment are met.

[0080] To improve the cooling of the product from the second subsystem 2 for liquid separation, a refrigeration module 19 is also included. One end of the refrigeration module 19 is connected to the primary separation module 17, and the other end is connected to the second subsystem 2 to achieve timely cooling. A tail gas collection module 20 is set at the end of the experimental pipeline of the second subsystem 2. The tail gas collection module 20 is connected to the second output end of the secondary separation module 18 to treat the gas after the experiment in a timely manner and avoid environmental pollution.

[0081] In actual use, the device of this application first obtains on-site mine data, determines and records the basic data and process conditions of the reservoir prototype, selects a similarity criterion system, then selects a similarity scale factor, and determines the geometric dimensions, steam injection temperature, pressure, flow rate, dryness, time, injection-production pressure difference and other operating parameters of the proportional physical model body.

[0082] By regulating the liquid injection unit and gas injection unit in the supply subsystem, the input of various gases and the output of corresponding crude oil liquid are adjusted for the fluid with determined relevant parameters, and the fluid configuration is completed. During this process, the one-way valves on the first pipeline 21, the second pipeline 22, the third pipeline 23, and the fourth pipeline 24 can effectively prevent the backflow of injected gas and liquid to the site. Based on the pressure provided by the gas pressurization module 8 and the liquid injection pump, the smooth injection of gas-liquid mixture in the pipeline is ensured. The corresponding pipeline is selected according to actual needs. Fire-driven mining simulation experiment is carried out through the first subsystem 1, and steam mining simulation experiment is carried out through the second subsystem 2.

[0083] Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features; and these modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. An oil production experimental apparatus, characterized in that, include: Supply subsystem, first subsystem (1), second subsystem (2), data subsystem; The supply subsystem includes a liquid injection unit and a gas injection unit, which are connected by pipelines. The input ends of the first subsystem (1) and the second subsystem (2) are provided with liquid pipelines that connect to the liquid injection unit and gas pipelines that connect to the gas injection unit. The liquid pipelines and gas pipelines connected to the first subsystem (1) are respectively connected to the gas pipelines and liquid pipelines connected to the second subsystem (2). The outputs of the first subsystem (1) and the second subsystem (2) are both connected to the data subsystem via pipelines.

2. The oil production experimental apparatus according to claim 1, characterized in that, The liquid injection unit includes: a liquid injection pump, several intermediate buffer containers (3), and a fluid preheating module (4) connected in sequence; The other end of the fluid preheating module (4) is connected to the first subsystem (1) and the second subsystem (2) through a liquid pipeline.

3. The oil production experimental apparatus according to claim 2, characterized in that, The liquid injection pump includes a variable speed injection pump (5) and a constant speed and constant pressure pump (6), and the variable speed injection pump (5) and the constant speed and constant pressure pump (6) are connected to several intermediate buffer containers (3) through a fifth pipeline (25).

4. The oil production experimental apparatus according to claim 3, characterized in that, The gas injection unit includes an air compressor (7), a gas booster module (8), a gas storage pipe (9), a pressure regulator (10), a flow controller (11), and a gas heat exchanger (13) connected in sequence. The gas booster module (8) is connected to the high-pressure gas distribution module (12) via a pipeline; The gas heat exchanger (13) is connected to the first subsystem (1) and the second subsystem (2) respectively through gas pipelines; The flow controller (11) is connected to the fifth pipeline (25) via a pipeline.

5. The oil production experimental apparatus according to claim 4, characterized in that, The high-pressure gas distribution module (12) includes a transfer mixing cylinder (122) and several gas delivery cylinders (121) containing different gases; Several of the gas cylinders (121) are connected to one end of the intermediate gas mixing cylinder (122) via pipelines; The other end of the transfer mixing cylinder (122) is connected to the gas pressurization module (8) via a pipeline.

6. The oil production experimental apparatus according to claim 1, characterized in that, The first subsystem (1) adopts a thermal recovery subsystem, and the second subsystem (2) adopts a pyrolysis subsystem.

7. The oil production experimental apparatus according to claim 6, characterized in that, The model of the first subsystem (1) is equipped with a heating and heat preservation device, an ignition device and a hydraulic tracking device; The heating device is used to heat the cavity of the first subsystem (1); The ignition simulation device is used to simulate fire-driven mining experiments; The hydraulic tracking device is used to regulate the internal pressure of the first subsystem (1).

8. The oil production experimental apparatus according to claim 7, characterized in that, The model of the first subsystem (1) includes several horizontal and vertical wells.

9. The oil production experimental apparatus according to claim 6, characterized in that, The data subsystem includes two output measurement units (14) and two data acquisition units (15); The two data acquisition units (15) are respectively installed on the first subsystem (1) and the second subsystem (2); The two output metering units (14) are respectively connected to the output terminals of the first subsystem (1) and the second subsystem (2) through pipelines.

10. The oil production experimental apparatus according to claim 9, characterized in that, The data subsystem also includes a vacuum unit, a back pressure control unit (16), a primary separation module (17), and a secondary separation module (18); The secondary separation module (18) has an input terminal and a first output terminal; One end of the back pressure control unit (16) is connected to the first subsystem (1) through a pipeline, and the other end of the back pressure control unit (16) is connected to the input end of the secondary separation module (18) through a pipeline. The first output end of the secondary separation module (18) is connected to the output metering unit (14) through a pipeline. One end of the primary separation module (17) is connected to the second subsystem (2) via a pipeline, and the other end of the primary separation module (17) is connected to one end of the vacuum unit via a pipeline. The other end of the vacuum unit is connected to the input end of the secondary separation module (18) via a pipeline. The first output end of the secondary separation module (18) is connected to the output metering unit (14) via a pipeline.

11. The oil production experimental apparatus according to claim 10, characterized in that, The data subsystem also includes a refrigeration module (19) and an exhaust gas collection module (20). The secondary separation module (18) also has a second output terminal. One end of the refrigeration module (19) is connected to the primary separation module (17), and the other end of the refrigeration module (19) is connected to the second subsystem (2). The exhaust gas collection module (20) is connected to the second output terminal of the secondary separation module (18).

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