High-pressure well network dynamic seepage visualization simulation device

Abstract

This utility model relates to the field of reservoir physical simulation technology, and provides a high-pressure well network dynamic seepage visualization simulation device. The device includes: a pressure-resistant model body, which forms a sealed cavity inside, and the sealed cavity is filled with a porous medium to simulate the formation; the sealed cavity is an all-metal pressure-resistant cavity; a well network structure is set in the porous medium, and the well network structure includes multiple wellheads, each of which is dynamically configured as a water injection well or a production well; a fluid injection device is connected to the multiple wellheads for injecting fluid into the wellheads configured as water injection wells and extracting fluid from the wellheads configured as production wells; a multi-point monitoring device includes multiple monitoring probes distributed in the porous medium for real-time acquisition of seepage parameters at multiple locations in the porous medium; a controller is electrically connected to both the fluid injection device and the multi-point monitoring device, and the controller controls the fluid injection system to perform injection and production operations and controls the touch screen to display seepage parameters, thereby improving the flexibility of well network simulation and the overall practicality of the device.

Description

Technical Field

[0001] This utility model relates to the field of reservoir physical simulation technology, and in particular to a high-pressure well network dynamic seepage visualization simulation device. Background Technology

[0002] In the field of oil and gas extraction, well network simulation technology is a key experimental method for studying the fluid transport patterns within reservoirs.

[0003] However, existing technologies still have many shortcomings in achieving comprehensive and accurate well network simulation. First, the pressure resistance of existing models is relatively low, making it impossible to simulate the real formation pressure environment of medium- to high-permeability reservoirs, resulting in low agreement between experimental data and actual operating conditions. Second, the monitoring points of existing models are sparsely distributed, typically with only a few sensors placed at key locations (such as near the wellhead), failing to cover the entire model area and making it difficult to accurately capture subtle changes in the local pressure field, such as inter-well disturbances. Utility Model Content

[0004] This invention provides a dynamic seepage visualization simulation device for high-pressure well networks, which solves the problems of low pressure resistance of the main body of the model and sparse distribution of monitoring points in the existing model.

[0005] This utility model provides a high-pressure well network dynamic seepage visualization simulation device, including:

[0006] The pressure-resistant model body has a sealed cavity inside, which is filled with a porous medium to simulate a geological formation; the sealed cavity is an all-metal pressure-resistant cavity.

[0007] A well network structure is disposed in the porous medium, the well network structure including multiple wellheads, each of the wellheads being dynamically configured as an injection well or a production well;

[0008] A fluid injection device, connected to the plurality of wellheads, is used to inject fluid into the wellheads configured as injection wells and to extract fluid from the wellheads configured as production wells;

[0009] A multi-point monitoring device includes multiple monitoring probes distributed in the porous medium for real-time acquisition of seepage parameters at multiple locations in the porous medium.

[0010] The controller is electrically connected to both the fluid injection device and the multi-point monitoring device. The controller is used to control the fluid injection device to perform injection and extraction operations, and to control the touch screen to display the seepage parameters.

[0011] According to the present invention, a dynamic seepage visualization simulation device for high-pressure well networks is provided, wherein the seepage parameters include pressure data and oil-water saturation data;

[0012] The monitoring probe includes multiple pressure transmitters and multiple resistivity probes;

[0013] The pressure transmitter and the resistivity probe are interspersed in the porous medium;

[0014] The pressure transmitter is used to collect pressure data from the pressure detection point at each wellhead.

[0015] The resistivity probe is used to collect the oil-water saturation data at each wellhead saturation detection point.

[0016] According to the present invention, a dynamic seepage visualization simulation device for high-pressure well network is provided, wherein the well network structure is a nine-point well network, including nine wellheads arranged in a 3×3 matrix.

[0017] According to the present invention, a dynamic seepage visualization simulation device for high-pressure well networks is provided, wherein the fluid injection device includes multiple fluid delivery pumps and an electromagnetic valve matrix connected to multiple wellheads;

[0018] The controller is used to control the on / off state of each valve in the solenoid valve matrix to dynamically configure any of the wellheads.

[0019] According to the present invention, a dynamic seepage visualization simulation device for high-pressure well networks is provided, wherein the controller includes:

[0020] A central processing unit, one end of which is electrically connected to the touch display screen;

[0021] A communication unit, one end of which is electrically connected to the other end of the central processing unit; the other end of which is electrically connected to each of the fluid delivery pumps;

[0022] The central processing unit is used to receive user input signals from the touch screen and convert the user input signals into control command messages;

[0023] The communication unit is used to receive control command messages from the central processing unit and send the control command messages to each of the fluid delivery pumps.

[0024] According to the present invention, a dynamic seepage visualization simulation device for high-pressure well networks is provided, wherein the communication unit is connected to each of the fluid delivery pumps via an RS485 communication bus.

[0025] According to the present invention, a dynamic seepage visualization simulation device for high-pressure well networks is provided, wherein the fluid delivery pump is a horizontal flow pump.

[0026] According to the present invention, a dynamic seepage visualization simulation device for high-pressure well networks is provided, wherein a sand layer compaction device is provided at the top of the sealed cavity;

[0027] The sand compaction device includes a screw lifting mechanism and a compaction plate, which are used to compact the filled porous medium in a standardized manner.

[0028] The high-pressure well network dynamic seepage visualization simulation device provided by this utility model firstly addresses the problem of low pressure resistance of existing models by employing an all-metal pressure-resistant cavity as a sealed chamber. This design significantly improves the model's pressure resistance, enabling it to simulate the real formation pressure environment of medium-to-high permeability reservoirs, thus ensuring a high degree of consistency between experimental data and actual operating conditions. Secondly, to address the issue of sparse monitoring point distribution, multiple monitoring probes are distributed within the porous medium. These probes can collect seepage parameters at multiple locations within the porous medium in real time, comprehensively covering the entire model area. This dense monitoring point layout can accurately capture local pressure changes and inter-well interference effects, solving the problem of existing technologies' difficulty in accurately monitoring subtle changes in the local pressure field, thereby improving the flexibility of well network simulation and the overall practicality of the device. Attached Figure Description

[0029] To more clearly illustrate the technical solutions in this utility model 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 this utility model. For those skilled in the art, other drawings can be obtained from these drawings without creative effort.

[0030] Figure 1 This is a schematic diagram of the structure of the high-pressure well network dynamic seepage visualization simulation device provided by this utility model.

[0031] Figure 2 This is a schematic diagram of the controller provided by this utility model.

[0032] Figure label:

[0033] 10: Pressure-resistant model body; 20: Well network structure; 30: Fluid injection device; 40: Multi-point monitoring device; 50: Controller; 60: Touch screen display; 51: Central processing unit; 52: Communication unit. Detailed Implementation

[0034] To make the objectives, technical solutions, and advantages of this utility model clearer, the technical solutions of this utility model will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this utility model, not all embodiments. Based on the embodiments of this utility model, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this utility model.

[0035] It should be noted that in the description of this utility model, the terms "first" and "second" are used for descriptive purposes only and should not be construed as indicating or implying relative importance or implicitly specifying the indicated technical features. Therefore, a feature defined with "first" or "second" may explicitly or implicitly include one or more of that feature. The terms "comprising," "including," "having," and their variations all mean "including but not limited to," unless otherwise specifically emphasized.

[0036] In the description of this application, it should be noted that, unless otherwise expressly specified and limited, the terms "electrical connection," "electrical connection," or "communication electrical connection" should be interpreted broadly. For example, "electrical connection," "electrical connection," or "communication electrical connection" can refer not only to a physical electrical connection, but also to an electrical connection or a signal electrical connection. For instance, it can be a direct electrical connection, i.e., a physical electrical connection, or an indirect electrical connection through at least one intermediate component, as long as the circuit is connected. It can also refer to the internal connection between two components. A signal electrical connection can refer not only to a signal electrical connection through a circuit, but also to a signal electrical connection through a medium, such as radio waves. Those skilled in the art can understand the specific meaning of the above terms in this application based on the specific circumstances.

[0037] Figure 1 This is a schematic diagram of the structure of the high-pressure well network dynamic seepage visualization simulation device provided by this utility model, as shown below. Figure 1 As shown, the device includes:

[0038] The pressure-resistant model body 10 has a sealed cavity inside, which is filled with a porous medium to simulate a geological formation; the sealed cavity is an all-metal pressure-resistant cavity.

[0039] A well network structure 20 is disposed in the porous medium, the well network structure including multiple wellheads, each of the wellheads being dynamically configured as a water injection well or a production well;

[0040] A fluid injection device 30 is connected to the plurality of wellheads for injecting fluid into the wellheads configured as injection wells and extracting fluid from the wellheads configured as production wells;

[0041] The multi-point monitoring device 40 includes multiple monitoring probes distributed in the porous medium, used to collect seepage parameters at multiple locations in the porous medium in real time;

[0042] The controller 50 is electrically connected to both the fluid injection device and the multi-point monitoring device. The controller is used to control the fluid injection device to perform injection and extraction operations, and to control the touch screen 60 to display the seepage parameters.

[0043] Specifically, the high-pressure well network dynamic seepage visualization simulation device includes a pressure-resistant model body 10, a well network structure 20, a fluid injection device 30, a multi-point monitoring device 40, and a controller 50.

[0044] The pressure-resistant model body 10 is the core load-bearing component of the entire simulation device, providing a controllable physical space capable of simulating the underground formation environment. In this embodiment, the pressure-resistant model body 10 forms a sealed cavity with defined internal dimensions, such as 500mm × 500mm × 50mm. This sealed cavity is used to contain porous media for simulating the formation. The porous media is typically quartz sand, whose pore structure simulates the reservoir space and seepage channels of a real formation. The sealed cavity is pressure-bearing; for example, its maximum pressure resistance can reach 0.5MPa to simulate pressure changes within the formation during injection and production.

[0045] Here, the main body of the pressure-resistant model is preferably an all-metal pressure-resistant cavity. The use of all-metal materials (such as stainless steel) is primarily based on the following considerations: First, metal materials possess excellent mechanical strength and rigidity, capable of withstanding the pressure generated by the internal fluid during the experiment (e.g., 0.5 MPa) without significant deformation. Deformation of the cavity would alter its internal volume and the stress state of the porous medium, thus affecting the accuracy of the experiment. Second, metal materials have stable chemical properties and are less likely to react with the fluids used in the experiment (water, oil, chemicals, etc.), ensuring the purity of the experimental environment.

[0046] The well network structure 20 is set in a porous medium and its function is to simulate the layout of water injection wells and production wells (oil wells) in an oil field. The well network structure 20 includes multiple wellheads that penetrate or partially penetrate the porous medium.

[0047] It should be noted that the function of each wellhead is not fixed, but can be dynamically configured as an injection well or a production well. This means that researchers can flexibly change the role of any wellhead according to different simulation schemes (e.g., different injection-production well network patterns, different development stages), thereby simulating various oilfield development schemes.

[0048] The fluid injection device 30 is connected to multiple wellheads of the well network structure 20. Its function is to perform specific injection and production operations according to the configuration of the wellheads. When a wellhead is configured as a water injection well, the fluid injection device injects fluid (such as water) into that wellhead; when a wellhead is configured as a production well, the fluid injection device extracts fluid (such as oil or an oil-water mixture) from that wellhead. In this way, the process of injecting displacement fluid (water) into the formation and extracting crude oil from the formation during oilfield development is simulated.

[0049] The multi-point monitoring device 40 is used to monitor the fluid seepage state inside the simulated formation in real time. It includes multiple monitoring probes distributed in a preset pattern at different locations within the porous medium. By deploying monitoring probes at multiple key locations, seepage parameters can be collected at multiple locations throughout the simulated formation. These seepage parameters are key data for evaluating the effectiveness of different development schemes; they may include parameters such as pressure and saturation.

[0050] The controller 50 is the control and data processing center of the entire device. It is electrically connected to both the fluid injection device 30 and the multi-point monitoring device 40. On one hand, the controller 50 controls the fluid injection device 30 to perform complex injection and production operations according to preset experimental procedures or real-time user commands, such as controlling the flow rate of the injected fluid, the total injection volume, and the switching of injection and production status at each wellhead. On the other hand, the controller 50 receives real-time seepage parameters collected from the multi-point monitoring device 40, processes and analyzes this data, and finally dynamically displays the seepage parameters in a visual form (e.g., pressure contour maps, saturation contour maps) through a connected touch screen 60 or other display device.

[0051] The device provided in this embodiment addresses the issue of low pressure resistance in existing models by employing an all-metal pressure-resistant cavity as a sealed chamber. This design significantly improves the model's pressure resistance, enabling it to simulate the real formation pressure environment of medium-to-high permeability reservoirs, thus ensuring a high degree of agreement between experimental data and actual operating conditions. Secondly, to address the sparse distribution of monitoring points, multiple monitoring probes are distributed within the porous medium. These probes can collect seepage parameters at multiple locations within the porous medium in real time, comprehensively covering the entire model area. This dense layout of monitoring points accurately captures local pressure changes and inter-well interference effects, solving the problem of existing technologies' difficulty in accurately monitoring subtle changes in the local pressure field, thereby improving the flexibility of well network simulation and the overall practicality of the device.

[0052] Based on the above embodiments, the seepage parameters include pressure data and oil-water saturation data;

[0053] The monitoring probe includes multiple pressure transmitters and multiple resistivity probes;

[0054] The pressure transmitter and the resistivity probe are interspersed in the porous medium;

[0055] The pressure transmitter is used to collect pressure data from the pressure detection point at each wellhead.

[0056] The resistivity probe is used to collect the oil-water saturation data at each wellhead saturation detection point.

[0057] Specifically, in this embodiment, the monitoring probe includes multiple pressure transmitters and multiple resistivity probes. The pressure transmitters and resistivity probes are distributed alternately in the porous medium. The pressure transmitters are used to collect pressure data at each wellhead pressure detection point, and the resistivity probes are used to collect oil-water saturation data at each wellhead saturation detection point.

[0058] A pressure transmitter is a sensor used to measure fluid pressure. It converts the sensed pressure signal into a standard electrical signal (such as a 4-20mA current signal) as an output. In this device, the pressure transmitter is used to acquire pressure data at its location in real time, thereby depicting the pressure field distribution throughout the porous medium.

[0059] A resistivity probe is a sensor that measures fluid saturation by utilizing the difference in conductivity (i.e., resistivity) between different fluids such as oil and water. Since water conducts electricity while oil does not, the oil-water saturation at that point can be calculated by measuring the overall resistivity of the medium surrounding the probe. In this device, the resistivity probe is used to collect oil-water saturation data at the saturation detection point.

[0060] To comprehensively acquire information about the pressure and saturation fields, pressure transmitters and resistivity probes are staggered in the porous medium. For example, pressure transmitters and resistivity probes can be arranged at intervals within a monitoring point grid, or both types of probes can be deployed simultaneously at key locations. For instance, multiple pressure and saturation monitoring points are set up around the wellhead, and pressure transmitters or resistivity probes are installed at these monitoring points.

[0061] The device provided in this embodiment, by concretizing the monitoring probe into a pressure transmitter and a resistivity probe and distributing them alternately, can simultaneously and accurately collect the two most critical seepage parameters, pressure and saturation, which greatly improves the data dimension and analysis depth of the simulation experiment.

[0062] Based on the above embodiments, the well network structure is a nine-point well network, including nine wellheads arranged in a 3×3 matrix.

[0063] Specifically, in this embodiment, the well network structure is a classic nine-point well network used in oilfield development. This well network structure includes nine wellheads arranged in a 3×3 matrix on a horizontal plane. The nine wellheads (black circles in the figure) form a square matrix. In a specific example, the entire model area is 500mm×500mm, and the horizontal and vertical spacing between the nine wellheads is 125mm.

[0064] Based on the above embodiments, the fluid injection device 30 includes a plurality of fluid delivery pumps and a matrix of solenoid valves connected to the plurality of wellheads;

[0065] The controller 50 is used to control the on / off state of each valve in the solenoid valve matrix to dynamically configure any of the wellheads.

[0066] Specifically, in order to achieve dynamic configuration of any wellhead, the fluid injection device in this embodiment includes multiple fluid delivery pumps and a matrix of solenoid valves connected to multiple wellheads.

[0067] The fluid delivery pump is the power source for fluid injection, responsible for providing a stable flow rate. The solenoid valve matrix is ​​a pipeline control network composed of multiple solenoid valves, located between the fluid delivery pump and each wellhead. Each wellhead has a corresponding solenoid valve connected to its pipeline.

[0068] The controller 50 dynamically configures the wellhead function by controlling the on / off state of each solenoid valve in the solenoid valve matrix. For example, when the controller 50 needs to configure wellhead 1 as a water injection well, it sends a command to open the solenoid valve connecting the fluid delivery pump outlet to wellhead 1, while simultaneously opening valves on other flow paths connected to wellhead 1 that may be closed. When wellhead 2 needs to be configured as a production well, the controller 50 opens the solenoid valve connecting wellhead 2 to the produced fluid collection pipeline. By programming the solenoid valve matrix, the function of any wellhead can be quickly and automatically switched, combining various complex injection and production schemes.

[0069] The device provided in this embodiment, by introducing a solenoid valve matrix, achieves rapid, accurate and automated control of wellhead functions. Compared with manual valve operation, this method greatly improves experimental efficiency and the flexibility of scheme switching, avoids human operation errors, and makes complex simulation experiments with multiple schemes over a long period of time possible, thereby enhancing the automation level and practicality of the device.

[0070] Based on the above embodiments, Figure 2 This is a schematic diagram of the controller provided by this utility model, as shown below. Figure 2 As shown, the controller 50 includes:

[0071] Central processing unit 51, one end of which is electrically connected to the touch display screen 60;

[0072] Communication unit 52, one end of which is electrically connected to the other end of the central processing unit 51; the other end of communication unit 52 is electrically connected to each of the fluid delivery pumps.

[0073] The central processing unit 51 is used to receive user input signals from the touch display screen 60 and convert the user input signals into control command messages;

[0074] The communication unit 52 is used to receive control command messages from the central processing unit 51 and send the control command messages to each of the fluid transfer pumps.

[0075] Specifically, the controller 50 includes a central processing unit 51 and a communication unit 52. The touch screen 60 is the human-machine interface. For example, a 15.6-inch color touch screen can be used. Experimenters can use this screen to input experimental parameters (such as experiment name, personnel, injection and production flow rates, etc.), issue control commands (such as start / stop experiment, switch wellhead functions, etc.), and view data and charts (such as pressure contour maps) processed by the central processing unit in real time.

[0076] The central processing unit 51 is the brain of the controller. For example, it can use an Intel i5 processor, equipped with 8GB of memory and a 128GB solid-state drive, running an operating system such as Windows 10. Its main functions are: to receive user input signals from the touch screen 60, and to convert these user input signals into specific control command messages according to preset software logic. At the same time, it is also responsible for receiving monitoring data transmitted back from the communication unit, performing calculations and processing, generating a visual cloud map, and finally displaying it on the touch screen 60.

[0077] The communication unit 52 serves as a bridge between the central processing unit 51 and external devices (such as fluid transfer pumps, data acquisition modules, etc.). One end of it is connected to the central processing unit 51 to receive control command messages generated by the central processing unit 51; the other end is electrically connected to each controlled external device to send out control command messages. Simultaneously, it is also responsible for receiving monitoring data from the data acquisition module of the multi-point monitoring device and transmitting it to the central processing unit 51.

[0078] Based on the above embodiments, the communication unit 52 is connected to each of the fluid transfer pumps via an RS485 communication bus.

[0079] Specifically, the communication unit 52 is connected to each fluid transfer pump via an RS485 communication bus, and the communication unit 52 is also connected to each of the fluid transfer pumps via an RS232 communication bus.

[0080] RS485 is a differential signal serial communication protocol characterized by strong anti-interference capabilities, long communication distances, and support for connecting multiple devices on a single bus (i.e., multi-station communication). In experimental environments with numerous electronic devices and potential electromagnetic interference, using an RS485 bus ensures stable and reliable transmission of control commands between the controller and the fluid transfer pump, preventing pump malfunction or parameter setting errors due to signal interference.

[0081] Based on the above embodiments, the fluid transfer pump is a horizontal flow pump.

[0082] Specifically, in this embodiment, the fluid transfer pump is preferably a horizontal flow pump. A horizontal flow pump is a pump capable of providing stable, precise, and pulsation-free fluid. Its characteristic is that, at a set flow rate, its output flow rate is essentially unaffected by changes in the outlet pressure (i.e., the pump's back pressure).

[0083] In reservoir simulation experiments, the pressure inside the model changes continuously as fluid is injected, which places high demands on the stability of the injection pump. Using a horizontal flow pump ensures that the fluid velocity injected into the formation remains at the set value regardless of pressure fluctuations within the model, which is consistent with the actual constant-flow water injection development method in oilfields.

[0084] Based on the above embodiments, a sand layer compaction device is provided at the top of the sealed cavity;

[0085] The sand compaction device includes a screw lifting mechanism and a compaction plate, which are used to compact the filled porous medium in a standardized manner.

[0086] Specifically, in order to ensure that the physical properties (such as porosity and permeability) of the porous media used in each experiment are consistent, in this embodiment, a sand layer compaction device is also provided at the top of the sealed cavity.

[0087] The sand layer compaction device specifically includes a screw lifting mechanism and a compaction plate. After filling with porous media such as quartz sand, the screw lifting mechanism can be operated to move the compaction plate downwards, applying a uniform and controllable pressure to the entire sand layer. By controlling the compaction force or compaction displacement to the same standard, the compaction degree after each sand filling can be ensured to be basically consistent, thereby achieving standardized compaction of the filled porous media.

[0088] The device provided in this embodiment of the utility model solves the problems of uneven pore structure and poor repeatability caused by artificial sand filling by adding a sand layer compaction device. It can ensure that the initial state of the simulated strata is standardized and repeatable before each experiment. This is crucial for ensuring the comparability and reliability of the results between different experimental schemes, and significantly improves the scientificity and rigor of the experiment.

[0089] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of this utility model, and not to limit it. Although this utility model 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. Such 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 this utility model.

Claims

1. A dynamic seepage visualization simulation device for high-pressure well networks, characterized in that, include: The pressure-resistant model body has a sealed cavity inside, which is filled with a porous medium to simulate a geological formation; the sealed cavity is an all-metal pressure-resistant cavity. A well network structure is disposed in the porous medium, the well network structure including multiple wellheads, each of the wellheads being dynamically configured as an injection well or a production well; A fluid injection device, connected to the plurality of wellheads, is used to inject fluid into the wellheads configured as injection wells and to extract fluid from the wellheads configured as production wells; A multi-point monitoring device includes multiple monitoring probes distributed in the porous medium for real-time acquisition of seepage parameters at multiple locations in the porous medium. The controller is electrically connected to both the fluid injection device and the multi-point monitoring device. The controller is used to control the fluid injection device to perform injection and extraction operations, and to control the touch screen to display the seepage parameters.

2. The high-pressure well network dynamic seepage visualization simulation device according to claim 1, characterized in that, The seepage parameters include pressure data and oil-water saturation data; The monitoring probe includes multiple pressure transmitters and multiple resistivity probes; The pressure transmitter and the resistivity probe are interspersed in the porous medium; The pressure transmitter is used to collect pressure data from the pressure detection point at each wellhead. The resistivity probe is used to collect the oil-water saturation data at each wellhead saturation detection point.

3. The high-pressure well network dynamic seepage visualization simulation device according to claim 1, characterized in that, The well network structure is a nine-point well network, comprising nine wellheads arranged in a 3×3 matrix.

4. The high-pressure well network dynamic seepage visualization simulation device according to any one of claims 1 to 3, characterized in that, The fluid injection device includes multiple fluid delivery pumps and a matrix of solenoid valves connected to the multiple wellheads; The controller is used to control the on / off state of each valve in the solenoid valve matrix to dynamically configure any of the wellheads.

5. The high-pressure well network dynamic seepage visualization simulation device according to claim 4, characterized in that, The controller includes: A central processing unit, one end of which is electrically connected to the touch display screen; A communication unit, one end of which is electrically connected to the other end of the central processing unit; the other end of which is electrically connected to each of the fluid delivery pumps; The central processing unit is used to receive user input signals from the touch screen and convert the user input signals into control command messages; The communication unit is used to receive control command messages from the central processing unit and send the control command messages to each of the fluid delivery pumps.

6. The high-pressure well network dynamic seepage visualization simulation device according to claim 5, characterized in that, The communication unit is connected to each of the fluid transfer pumps via an RS485 communication bus.

7. The high-pressure well network dynamic seepage visualization simulation device according to claim 6, characterized in that, The fluid transfer pump is a horizontal flow pump.

8. The high-pressure well network dynamic seepage visualization simulation device according to any one of claims 1 to 3, characterized in that, The top of the sealed cavity is equipped with a sand layer compaction device; The sand compaction device includes a screw lifting mechanism and a compaction plate, which are used to compact the filled porous medium in a standardized manner.

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