Electric heating horizontal well-oil reservoir coupling heat transfer simulation device and method

Abstract

The invention provides an electric heating horizontal well-oil reservoir coupling heat transfer simulation device and method, and relates to the technical field of petroleum engineering. The injection system is connected with the simulated oil reservoir container and used for injecting fluid into the simulated oil reservoir container; the extraction system is connected with the simulated oil reservoir container and is used for extracting fluid from the simulated oil reservoir container; the electric heating module is arranged in the simulated horizontal well pipe; the temperature sensing systems are uniformly distributed in the simulated oil reservoir container; and the injection system, the extraction system, the electric heating module and the temperature sensing system are all in communication connection with the data processing unit. According to the method, the device is adopted, through more accurate simulation and analysis, operation parameters of electric heating can be optimized, a scientific basis can be provided for long-term management and maintenance of an oil field, operation risks are reduced, and economic benefits are enhanced.

Description

Technical Field

[0001] The present invention relates to the technical field of petroleum engineering, and in particular to an electrically heated horizontal well-oil reservoir coupled heat transfer simulation device and method. Background Art

[0002] Traditional extraction methods such as water flooding and gas flooding face numerous challenges in the development of high-viscosity and low-permeability oilfields. For example, the poor fluidity of high-viscosity crude oil makes it difficult to flow through the pores of the reservoir, while low permeability further limits the fluid's migration rate. Furthermore, while heat recovery technologies such as steam injection can improve crude oil fluidity, they consume significant energy, have high operating costs, and can cause irreversible damage to the reservoir's geological structure.

[0003] Electric heating technology directly heats the oil reservoir by installing electric heating elements in the wellbore. This technology offers a relatively environmentally friendly and energy-efficient method for reservoir heating. Compared to steam injection, electric heating achieves more uniform heating and reduces heat loss, thereby improving energy efficiency. Electric heating technology is particularly suitable for marginal oil fields and complex reservoirs that are difficult to extract using traditional methods.

[0004] Despite significant theoretical advantages, electric heating technology still faces numerous limitations in practical application. For example, the heat and pressure resistance of electric heating elements needs to be further improved to accommodate the high-temperature and high-pressure environments found in deep reservoirs. Furthermore, energy distribution and transfer efficiency must be optimized, including improving heating uniformity and optimizing energy conversion efficiency. Furthermore, the current lack of a mature reservoir management and monitoring solution for electric heating technology has limited its widespread adoption in large-scale commercial applications.

[0005] Therefore, there is an urgent need for an electrically heated horizontal well-reservoir coupled heat transfer simulation device and method to solve the above technical problems. Summary of the Invention

[0006] The present invention aims to provide an electrically heated horizontal well-reservoir coupled heat transfer simulation device and method that comprehensively considers the reservoir's geological characteristics, electrical heating parameters, and their impact on the reservoir environment, thereby optimizing and improving the efficiency of electrical heating technology. Through more precise simulation and analysis, not only can the operating parameters of electrical heating be optimized, but it can also provide a scientific basis for the long-term management and maintenance of oil fields, reduce operational risks, and enhance economic benefits. The various technical benefits achieved by the preferred technical solutions among the various technical solutions provided by this invention are detailed below.

[0007] To achieve the above objectives, the present invention provides the following technical solutions:

[0008] The present invention provides an electrically heated horizontal well-reservoir coupled heat transfer simulation device, comprising:

[0009] A simulated oil reservoir container with a simulated horizontal well pipe inside;

[0010] an injection system connected to the simulated oil reservoir container and used to inject fluid into the simulated oil reservoir container;

[0011] a production system connected to the simulated oil reservoir container and used to produce fluid from the simulated oil reservoir container;

[0012] An electric heating module is arranged in the simulated horizontal well pipe;

[0013] a temperature sensing system, uniformly distributed in the simulated oil reservoir container;

[0014] The data processing unit, the injection system, the extraction system, the electric heating module, and the temperature sensing system are all communicatively connected to the data processing unit.

[0015] Preferably, the injection system comprises a first flow meter and a first pressure sensor for controlling the speed and pressure of the injected fluid;

[0016] The production system includes multiple production outlets, each of which is equipped with a second flow meter, a sample collector, a second pressure sensor and a temperature sensor for real-time monitoring and analysis of the state of the produced fluid.

[0017] Preferably, the data processing unit includes a control module, and the injection system and the production system are both communicatively connected to the control module, and the control module can automatically adjust the injection and production parameters according to the simulation purpose and set conditions.

[0018] Preferably, the electric heating module includes a plurality of heating sections with adjustable lengths, each heating section includes an independent heating unit, each of the heating units is communicatively connected to the control module, and each of the heating units is equipped with an independent temperature monitoring sensor, and each of the heating units is equipped with a control interface for setting independent working parameters for each of the heating units.

[0019] Preferably, the electric heating module includes a safety monitoring system, which is electrically connected to the control module and is used to monitor the current, voltage and temperature of the electric heating module in real time, and can automatically adjust or cut off power to prevent the electric heating module from overheating and electrical failure.

[0020] Preferably, a plurality of adjustable baffle systems are provided in the simulated reservoir container for simulating the multi-layer structural characteristics of different strata.

[0021] Preferably, the simulated oil reservoir container has a modular structure, and the size and shape of the simulated oil reservoir container can be adjusted through the modular structure.

[0022] Preferably, the simulated oil reservoir container is made of stainless steel.

[0023] Preferably, the simulated oil reservoir container is filled with oil reservoir simulation material.

[0024] A method for simulating coupled heat transfer of an electrically heated horizontal well and an oil reservoir is provided, using the aforementioned coupled heat transfer simulation device for electrically heated horizontal wells and an oil reservoir, and includes the following steps:

[0025] S1: Setting simulation parameters: setting the reservoir simulation material in the simulated reservoir container according to the characteristics of the target reservoir, adjusting the size and shape of the reservoir container, and the simulated geological structure;

[0026] S2: Configure the electric heating module: according to the simulation requirements, set the heating temperature, power and heating time of the electric heating module, and adjust the position and length of the electric heating module;

[0027] S3: Implement injection operation: inject the selected fluid into the simulated reservoir container through the injection system, and control the injection rate and pressure;

[0028] S4: Execute heating operation: start the electric heating module and heat according to the preset temperature;

[0029] S5: Produced fluid: Produce fluid from the simulated reservoir container through the production system and monitor the quantity and quality of the produced fluid to evaluate the effects of electrical heating and fluid injection on the reservoir extraction efficiency;

[0030] S6: Data acquisition and analysis: Use the temperature sensing system to collect real-time temperature data in the reservoir, analyze temperature changes and fluid dynamics through the data processing unit, and evaluate the effects of heating and injection operations;

[0031] S7: Optimize simulation operations: Based on the preliminary simulation results, adjust the electric heating parameters or fluid injection parameters, repeat the simulation process to optimize the reservoir development strategy, and use the analysis and suggestions provided by the data processing unit to guide the operation optimization;

[0032] S8: Comprehensive evaluation and report generation: Comprehensively analyze all collected data, including temperature distribution, fluid dynamics, and recovery efficiency, and generate detailed simulation reports to evaluate the effectiveness of different electric heating strategies and fluid injection strategies.

[0033] The present invention provides an electrically heated horizontal well-reservoir coupled heat transfer simulation device and method, which has the following beneficial effects:

[0034] 1. A highly integrated modular design enables the electric heating module, temperature sensing system, injection system, and extraction system to work seamlessly together on the same platform. This integrated design not only simplifies the operating process but also improves equipment reliability and maintenance efficiency.

[0035] 2. By precisely controlling the heating parameters of the electric heating module, such as temperature, power, and time, more uniform and efficient heating of the target area within the reservoir can be achieved. Precise heating can significantly improve the fluidity of high-viscosity oil, thereby increasing oil and gas recovery, especially in difficult-to-access reservoirs;

[0036] 3. By simulating different combinations of electrical heating and fluid injection parameters, developers can evaluate the effectiveness of various production stimulation strategies, thereby guiding actual oilfield development. Simulation results can be used to optimize oilfield development plans, reduce trial and error costs, and ensure the economic and efficient development activities.

[0037] 4. The temperature sensing system and data processing unit provide a complete set of data monitoring, analysis and feedback mechanisms. They can not only monitor temperature changes in the reservoir in real time, but also analyze data and provide operational recommendations to help operators make quick decisions and improve response efficiency.

[0038] 5. The electric heating module incorporates advanced adaptive temperature control technology, automatically adjusting heating parameters based on the thermal response of the reservoir material. This intelligent temperature management not only ensures heating efficiency but also significantly reduces the risk of overheating. BRIEF DESCRIPTION OF THE DRAWINGS

[0039] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required for use in the embodiments or the description of the prior art. Obviously, the drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative work.

[0040] Figure 1 This is a schematic structural diagram of an embodiment of an electrically heated horizontal well-reservoir coupled heat transfer simulation device according to the present invention;

[0041] Figure 2 It is a schematic cross-sectional view of the simulated oil reservoir container in the present invention.

[0042] In the figure: 1. Simulated oil reservoir container; 10. Simulated horizontal well pipe; 2. Injection system; 21. First flow meter; 22. First pressure sensor; 3. Production system; 30. Production outlet; 31. Second flow meter; 32. Sample collector; 33. Second pressure sensor; 4. Electric heating module; 5. Temperature sensing system; 51. Temperature measuring point; 6. Data processing unit. DETAILED DESCRIPTION

[0043] To make the objectives, technical solutions, and advantages of the present invention more apparent, the technical solutions of the present invention will be described in detail below. Obviously, the embodiments described are only some of the embodiments of the present invention, not all of them. Based on the embodiments of the present invention, all other implementations obtained by those of ordinary skill in the art without inventive effort are within the scope of protection of the present invention.

[0044] In the description of the present invention, it should be understood that the terms "center", "lateral", "length", "width", "height", "up", "down", "front", "back", "left", "right", "vertical", "horizontal", "top", "bottom", "inside", "outside", "side", etc., indicating the orientation or position relationship, are based on the orientation or position relationship shown in the accompanying drawings, and are only for the convenience of describing the present invention and simplifying the description, rather than indicating or implying that the device or element referred to must have a specific orientation, be constructed and operated in a specific orientation, and therefore should not be understood as limiting the present invention.

[0045] It should also be noted that, in the description of the present invention, unless otherwise expressly specified or limited, the terms "mounted," "connected," and "connected" should be understood broadly. For example, they may refer to fixed, detachable, or integral connections; mechanical or electrical connections; and direct or indirect connections through an intermediary. Those skilled in the art will understand the specific meanings of the above terms in the present invention depending on the specific circumstances.

[0046] Figure 1 Schematic diagram of the structure of this embodiment, Figure 2 is a cross-sectional view of the simulated reservoir container, such as Figure 1 and Figure 2 As shown, this embodiment provides an electrically heated horizontal well-reservoir coupled heat transfer simulation device, including a simulated reservoir container 1, an injection system 2, a production system 3, an electric heating module 4, a temperature sensing system 5 and a data processing unit 6.

[0047] Among them, the simulated oil reservoir container 1 is made of stainless steel material that is resistant to high pressure, high temperature and chemical corrosion. Multiple adjustable partition systems are set in the simulated oil reservoir container 1, and the interior is filled with oil reservoir simulation materials to simulate the multi-layer structural characteristics of different formations to adapt to different oil reservoir simulation needs.

[0048] The simulated horizontal well pipe 10 is arranged inside the simulated reservoir container 1 in this embodiment, and the simulated reservoir container 1 has a modular structure. The size and shape of the simulated reservoir container can be adjusted according to different reservoir characteristics through the modular structure, and can adapt to more reservoir geometries and geological conditions.

[0049] like Figure 1 As shown, the injection system 2 in this embodiment is connected to the simulated oil reservoir container 1 and is used to inject fluid into the simulated oil reservoir container 1. When in use, the selected fluid, such as water, oil or gas, is injected into the simulated oil reservoir through the injection system 2 to simulate the injection process of an actual oil field.

[0050] The injection system 2 includes a first flow meter 21 and a first pressure sensor, which are used to control the speed and pressure of the injected fluid to study the effects of different injection parameters on reservoir performance.

[0051] Specifically, the first flowmeter 21 in this embodiment is a high-precision flowmeter for precisely controlling the injection rate and pressure of fluids such as water, oil, and gas. Furthermore, the injection system 2 in this embodiment is communicatively connected to the control module in the data processing unit 6 to achieve automated and precise control of the injection operation.

[0052] like Figure 1 As shown, the production system 3 in this embodiment is connected to the simulated oil reservoir container 1, and is used to produce fluid from the simulated oil reservoir container 1, monitor the quantity and quality of the produced fluid, and evaluate the effects of electric heating and fluid injection on the oil reservoir extraction efficiency.

[0053] Specifically, the production system 3 in this embodiment includes multiple independent production ports 30, each of which is equipped with a second flow meter 31, a sample collector 32, a second pressure sensor 33 and a temperature sensor for real-time monitoring and analysis of the state of the produced fluid.

[0054] like Figure 2 As shown, the electric heating module 4 in this embodiment is installed within a simulated horizontal wellbore 10. The electric heating module 4 includes multiple heating segments with adjustable lengths, each of which includes independent heating units. Each heating unit is communicatively connected to the control module of the data processing unit 6. Each heating unit is equipped with an independent temperature monitoring sensor, and a dedicated control interface is provided for each heating unit, allowing the user to set independent operating parameters for each heating unit, such as temperature setting, heating power, and heating time.

[0055] Each heating unit in this embodiment adopts an independent PID temperature control system and is equipped with a high-temperature-resistant heating wire with adjustable length, allowing precise control of heating temperature and power.

[0056] Specifically, each heating unit in this embodiment is composed of multiple electric heating elements connected in series or parallel, and each element is equipped with an independent temperature monitoring sensor, allowing the heating temperature of each element to be independently regulated, so as to facilitate dynamic adjustment of the heating temperature and power according to experimental requirements through intelligent temperature control technology, thereby ensuring heating uniformity and efficiency.

[0057] Optionally, each heating unit in this embodiment is designed to maximize heat energy transfer efficiency, use advanced thermal insulation materials to reduce heat loss, and ensure that heating energy is directly transferred to the target reservoir area.

[0058] Preferably, the electric heating module 4 in this embodiment includes a safety monitoring system, which is electrically connected to the control module and is used to monitor the current, voltage and temperature of the electric heating module 4 in real time, and can automatically adjust or cut off the power to prevent the electric heating module 4 from overheating and electrical failure, thereby ensuring safe operation.

[0059] The temperature sensing system 5 in this embodiment uses multiple high-precision (±0.1°C) and fast response time (≤2 seconds) multi-point temperature measurement thermocouples. Figure 2 As shown, the temperature sensing system 5 in this embodiment includes multiple temperature measurement points 51 evenly distributed within the simulated reservoir container 1 for real-time monitoring and recording of temperature distribution. Specifically, the temperature sensing system 5 in this embodiment employs a high-density layout, evenly distributed around the simulated horizontal wellbore 10, ensuring comprehensive temperature coverage from the wellhead to various depths in the reservoir.

[0060] This embodiment provides a temperature sensing system 5 with a high-density arrangement of thermocouples as the core to ensure the comprehensiveness and accuracy of data acquisition, temperature recording and monitoring. It can accurately measure the temperature gradient inside the reservoir and realize real-time temperature monitoring and gradient analysis throughout the reservoir to optimize thermal management and improve oil and gas extraction efficiency.

[0061] Furthermore, all thermocouple sensors in this embodiment are connected to the data processing unit via a high-speed communication network to transmit measurement data in real time, thereby minimizing delays and optimizing real-time data processing.

[0062] As an optional embodiment, the data processing unit 6 in this embodiment integrates a high-speed data processing chip and advanced data analysis software, using the latest processors and algorithms to rapidly analyze the large amount of collected data. Specifically, the data processing unit 6 in this embodiment includes the ability to receive and process temperature data from thermocouples, fluid dynamics data, and reservoir simulation feedback in real time, supporting real-time analysis of temperature changes, fluid dynamics, and heat transfer processes, and adjusting simulation parameters through dynamic optimization feedback. It also has historical data learning capabilities, providing a scientific basis for further optimization.

[0063] The Data Processing Unit 6 supports complex data processing and simulation tasks, providing automated data acquisition, processing, and simulation optimization recommendations. A customized software platform offers a user-friendly interface and multiple parameter settings, allowing operators to adjust simulation parameters based on real-time data and optimize reservoir management strategies. The software also incorporates machine learning capabilities, enabling it to automatically provide recommendations for improving reservoir development based on historical operational data and current simulation results.

[0064] In this embodiment, the injection system 2, the production system 3, the electric heating module 4, and the temperature sensing system 5 are all communicatively connected to a data processing unit 6. The data processing unit 6 includes a control module, which utilizes a programmable logic controller (PLC). The injection system 2 and the production system 3 are both communicatively connected to the control module, capable of simulating the injection and production processes of different fluids (such as water, oil, and gas) in the reservoir, and optimizing heat transfer effects and fluid migration paths based on real-time data. The control module can automatically adjust injection and production parameters based on the simulation objectives and set conditions to optimize the efficiency and effectiveness of the overall simulation process.

[0065] This embodiment also provides a method for simulating coupled heat transfer between an electrically heated horizontal well and an oil reservoir, suitable for laboratory research and field application to optimize the design and operation of electrically heated oil wells. The method uses the aforementioned electrically heated horizontal well-reservoir coupled heat transfer simulation device and specifically includes the following steps:

[0066] S1: Setting simulation parameters: According to the characteristics of the target reservoir, the reservoir simulation material in the simulated reservoir container 1 is set, and the size and shape of the reservoir container, as well as the simulated geological structure, are adjusted.

[0067] S2: Configure the electric heating module: According to the simulation requirements, set the heating temperature, power and heating time of each electric heating unit in the electric heating module 4, and adjust the position and length of the electric heating module 4 to match the actual conditions of the simulated reservoir.

[0068] S3: Implement injection operation: inject the selected fluid, such as water, oil or gas, into the simulated reservoir container 1 through the injection system 2 to simulate the injection process of the actual oil field, control the injection rate and pressure, and study the impact of different injection parameters on the reservoir performance.

[0069] S4: Execute heating operation: start the electric heating module 4 and heat according to the preset temperature; continuously monitor the temperature changes in the oil reservoir to ensure uniform heating and achieve the required temperature distribution.

[0070] S5: Producing fluid: Producing fluid from the simulated reservoir container 1 through the production system, monitoring the amount and quality of the produced fluid to evaluate the effects of electrical heating and fluid injection on the reservoir extraction efficiency;

[0071] S6: Data acquisition and analysis: Use the temperature sensing system to collect real-time temperature data in the reservoir, analyze temperature changes and fluid dynamics through the data processing unit 6, and evaluate the effects of heating and injection operations;

[0072] S7: Optimize simulation operations: Based on the preliminary simulation results, adjust the electric heating parameters or fluid injection parameters, repeat the simulation process to optimize the reservoir development strategy, and use the analysis and suggestions provided by the data processing unit to guide the operation optimization;

[0073] S8: Comprehensive evaluation and report generation: Comprehensively analyze all collected data, including temperature distribution, fluid dynamics, and recovery efficiency, generate detailed simulation reports, evaluate the effectiveness of different electric heating strategies and fluid injection strategies, and provide a scientific basis for actual oilfield operations.

[0074] This electrically heated horizontal well-reservoir coupled heat transfer simulation method integrates injection and production data through a data processing unit 6. In conjunction with feedback from a temperature sensing system, the injection and production systems are coordinated and interactively controlled through the data processing unit 6. Advanced data analysis techniques (such as machine learning algorithms) are used to automatically adjust injection and production parameters based on simulation objectives and set conditions. Comprehensive analysis and optimization recommendations are also provided to optimize the efficiency and effectiveness of the overall simulation process. This method can accurately simulate complex reservoir conditions in a laboratory environment, helping to predict and evaluate the effectiveness of different electrical heating operation strategies, leading to more scientific and reasonable decision-making, and has important guiding significance for field applications.

[0075] The above method is described in detail below with reference to specific embodiments.

[0076] Example 1

[0077] Based on the actual conditions of the target reservoir, this example first configures a simulated reservoir container 1. This simulated reservoir container 1 is constructed from high-pressure, high-temperature stainless steel and filled with 40-mesh sandstone particles soaked in crude oil to simulate the porosity and permeability of a real reservoir. Multiple adjustable baffles are designed within the simulated reservoir container 1 to simulate the multi-layered structural characteristics of different strata. Furthermore, an electric heating module 4 is installed within a simulated horizontal wellbore 10, which has a total length of 80 cm. The module is divided into five independent heating sections, each equipped with an independent PID temperature control system for precise temperature and power control. Thermocouple sensors are evenly distributed around the wellbore and within the simulated reservoir at 2 cm intervals, totaling 50 sensors, enabling comprehensive, real-time monitoring of the reservoir temperature. An injection system 2 and a production system 3 are installed at either end of the simulated reservoir container 1. The injection system 2 is equipped with a high-precision flowmeter and pressure sensor to control the injection rate and pressure, while the production system 3 is equipped with a flowmeter and sample collector to record the volume and properties of the produced fluid.

[0078] The simulation parameters were set through the user interface of the data processing unit 6, including a heating temperature of 200°C, a power of 100-150 watts per heating unit, an injection fluid of 0.5% surfactant-containing water at a rate of 10 ml / min, and a simulation time of 24 hours. The sampling frequency of the thermocouple sensor system and the production monitoring system was set to once per second to ensure the real-time and integrity of the data during the experiment.

[0079] After the experiment started, the electric heating module 4 gradually raised the temperature to 200°C and maintained a stable state. During the heating process, water was continuously injected into the simulated reservoir through the injection system 2. At this time, the temperature sensing system monitored the temperature distribution inside the reservoir in real time. The data showed that the temperature around the wellbore rose rapidly and diffused outward along the wellbore, forming a stable temperature gradient, and heat was gradually transferred to the far end of the simulated reservoir. At the same time, the production system 3 began to collect fluid from the other end of the wellbore and record its volume, temperature, and viscosity. Experimental data showed that the viscosity of the produced fluid was significantly reduced, demonstrating that the electric heating and injection operations significantly improved the fluidity of the crude oil.

[0080] After the experiment, data processing unit 6 analyzed the collected temperature and fluid data. The results showed that the temperature distribution around the wellbore was uniform, and the diffusion of the injected fluid effectively enhanced heat transfer efficiency. By comparing the simulation results of different heating powers and injection rates, the data showed that increasing the heating power to 150 watts significantly improved the heat transfer rate, while controlling the injection rate between 10-15 ml / min could maximize the volume of produced fluid.

[0081] Example 2

[0082] Based on the actual conditions of the target reservoir, this embodiment first configures a simulated reservoir container 1. This simulated reservoir container 1 is made of high-pressure, high-temperature stainless steel and filled with 120-mesh sandstone particles soaked in crude oil to simulate the porosity and permeability of a real reservoir. Multiple adjustable baffle systems are designed within the simulated reservoir container 1 to simulate the multi-layered structural characteristics of different strata. Simultaneously, an electric heating module 4 is installed within the horizontal wellbore, which has a total length of 80 cm. The module is divided into five independent heating sections, each equipped with an independent PID temperature control system for precise temperature and power control. Thermocouple sensors are evenly distributed around the wellbore and within the simulated reservoir at 2 cm intervals, totaling 50 sensors, enabling comprehensive, real-time monitoring of the reservoir temperature. The injection and production systems are installed at either end of the container. The injection system is equipped with a high-precision flowmeter and pressure sensor to control the injection rate and pressure, while the production system is equipped with a flowmeter and sample collector to record the volume and properties of the produced fluid.

[0083] Based on the actual conditions of deep reservoirs, the simulation parameters were set as follows: heating temperature was 250°C, heating power was controlled at 200 watts per section, the injected fluid was heated carbon dioxide (CO2) gas, the injection pressure was 8 MPa, the injection flow rate was 20 ml / min, and the experiment duration was set to 48 hours. Temperature acquisition was performed twice per second to capture temperature gradients in complex formations. The flowmeter accuracy in the production system was set to 0.01 ml to monitor the details of fluid production under high-pressure conditions.

[0084] The electric heating module was activated, gradually raising the wellbore temperature to 250°C and maintaining it steadily. CO2 gas was then injected into the simulated reservoir via the injection system. A thermocouple sensing system recorded the temperature trends within the reservoir in real time. The data showed a rapid temperature rise in the heated zone and diffusion along the wellbore. The injected CO2 gas, due to a decrease in its dissolution pressure during diffusion, also raised the temperature deep within the reservoir. The production system recorded the process of fluid withdrawal from the reservoir, showing that initially, the produced fluid was primarily CO2, with a gradual admixture of crude oil as the experiment progressed.

[0085] After the experiment was completed, analysis revealed that the temperature distribution diagram showed that the synergistic effect of CO2 injection significantly accelerated heat transfer in the heated area and evenly distributed it deep into the reservoir. Furthermore, the cumulative oil-to-gas ratio increased significantly, indicating that high-temperature CO2 injection significantly improved crude oil mobility and recovery. Comparisons of different heating powers and injection pressures revealed that optimal recovery was achieved when the injection pressure was controlled at 7-8 MPa.

[0086] The above description is merely a specific embodiment of the present invention, but the scope of protection of the present invention is not limited thereto. Any modifications or substitutions that can be easily conceived by a person skilled in the art within the technical scope disclosed in the present invention should be included in the scope of protection of the present invention. Therefore, the scope of protection of the present invention should be based on the scope of protection of the claims.

Claims

1. An electrically heated horizontal well-reservoir coupled heat transfer simulation device, characterized in that: include: A simulated oil reservoir container with a simulated horizontal well pipe inside; an injection system connected to the simulated oil reservoir container and used to inject fluid into the simulated oil reservoir container; a production system connected to the simulated oil reservoir container and used to produce fluid from the simulated oil reservoir container; An electric heating module is arranged in the simulated horizontal well pipe; a temperature sensing system, uniformly distributed in the simulated oil reservoir container; The data processing unit, the injection system, the extraction system, the electric heating module, and the temperature sensing system are all communicatively connected to the data processing unit.

2. The electrically heated horizontal well-reservoir coupled heat transfer simulation device according to claim 1, characterized in that: The injection system includes a first flow meter and a first pressure sensor for controlling the speed and pressure of the injected fluid; The production system includes multiple production outlets, each of which is equipped with a second flow meter, a sample collector, a second pressure sensor and a temperature sensor for real-time monitoring and analysis of the state of the produced fluid.

3. The electrically heated horizontal well-reservoir coupled heat transfer simulation device according to claim 2, characterized in that: The data processing unit includes a control module. The injection system and the production system are both in communication with the control module. The control module can automatically adjust injection and production parameters according to simulation purposes and set conditions.

4. The electrically heated horizontal well-reservoir coupled heat transfer simulation device according to claim 3, characterized in that: The electric heating module includes multiple heating sections with adjustable lengths, each heating section includes an independent heating unit, each heating unit is communicatively connected to the control module, and each heating unit is equipped with an independent temperature monitoring sensor, and each heating unit is equipped with a control interface for setting independent working parameters for each heating unit.

5. The electrically heated horizontal well-reservoir coupled heat transfer simulation device according to claim 4, characterized in that: The electric heating module includes a safety monitoring system, which is electrically connected to the control module and is used to monitor the current, voltage and temperature of the electric heating module in real time, and can automatically adjust or cut off power to prevent overheating and electrical failure of the electric heating module.

6. The electrically heated horizontal well-reservoir coupled heat transfer simulation device according to any one of claims 1 to 5, characterized in that: A plurality of adjustable baffle systems are provided in the simulated oil reservoir container for simulating the multi-layer structural characteristics of different strata.

7. The electrically heated horizontal well-reservoir coupled heat transfer simulation device according to claim 6, characterized in that: The simulated oil reservoir container has a modular structure, and the size and shape of the simulated oil reservoir container can be adjusted through the modular structure.

8. The electrically heated horizontal well-reservoir coupled heat transfer simulation device according to any one of claims 1 to 5, characterized in that: The simulated oil reservoir container is made of stainless steel.

9. The electrically heated horizontal well-reservoir coupled heat transfer simulation device according to claim 8, characterized in that: The simulated oil reservoir container is filled with oil reservoir simulation material.

10. A method for simulating coupled heat transfer of electrically heated horizontal wells and oil reservoirs, characterized by: The electrically heated horizontal well-reservoir coupled heat transfer simulation device according to any one of claims 1 to 9 comprises the following steps: S1: Setting simulation parameters: setting the reservoir simulation material in the simulated reservoir container according to the characteristics of the target reservoir, adjusting the size and shape of the reservoir container, and the simulated geological structure; S2: Configure the electric heating module: according to the simulation requirements, set the heating temperature, power and heating time of the electric heating module, and adjust the position and length of the electric heating module; S3: Implement injection operation: inject the selected fluid into the simulated reservoir container through the injection system, and control the injection rate and pressure; S4: Execute heating operation: start the electric heating module and heat according to the preset temperature; S5: Produced fluid: Produce fluid from the simulated reservoir container through the production system and monitor the quantity and quality of the produced fluid to evaluate the effects of electrical heating and fluid injection on the reservoir extraction efficiency; S6: Data acquisition and analysis: Use the temperature sensing system to collect real-time temperature data in the reservoir, analyze temperature changes and fluid dynamics through the data processing unit, and evaluate the effects of heating and injection operations; S7: Optimize simulation operations: Based on the preliminary simulation results, adjust the electric heating parameters or fluid injection parameters, repeat the simulation process to optimize the reservoir development strategy, and use the analysis and suggestions provided by the data processing unit to guide the operation optimization; S8: Comprehensive evaluation and report generation: Comprehensively analyze all collected data, including temperature distribution, fluid dynamics, and recovery efficiency, and generate detailed simulation reports to evaluate the effectiveness of different electric heating strategies and fluid injection strategies.

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