Optimization method, device and electronic equipment for development and utilization of underground thermal energy

Abstract

The application provides an optimization method, device and electronic equipment for development and utilization of underground thermal energy, and belongs to the field of development and utilization of underground thermal energy. The method comprises the following steps: based on an initial production flow rate and a recharge temperature, transiently solving a heat reservoir-wellbore coupling model within a target system operation life to obtain pressure distribution and temperature distribution of the heat reservoir-wellbore coupling model; monitoring the wellhead temperature of a production well in the heat reservoir-wellbore coupling model based on the temperature distribution, and in the case that the wellhead temperature of the production well does not meet a set temperature threshold, adjusting an initial injection-production well spacing and jumping to the step of determining the initial injection-production well spacing for execution; monitoring the wellhead pressure of a recharge well in the heat reservoir-wellbore coupling model based on the pressure distribution, and in the case that the wellhead pressure of the recharge well does not meet a set pressure threshold, adjusting the initial production flow rate and jumping to the step of determining the initial production flow rate for execution. The application solves the defect that there is currently a lack of an integrated optimization method for development of multiple types of underground thermal energy and utilization on the ground.

Description

Technical Field

[0001] This invention relates to the field of geothermal energy development and utilization technology, covering shallow low-temperature energy, hydrothermal geothermal development and utilization, and underground thermal storage systems for cross-seasonal heating. Specifically, it relates to an optimization method for geothermal energy development and utilization, an optimization device for geothermal energy development and utilization, an electronic device, a machine-readable storage medium, and a computer program product. Background Technology

[0002] Geothermal energy is a clean and renewable energy source that is widely found in the Earth's internal rock formations and natural fluids. The common research approach for geothermal energy development and utilization separates underground heat extraction from above-ground heat utilization systems. However, geothermal energy development and utilization is an integrated above-ground and above-ground system engineering project. This integrated system engineering is influenced by various parameters, each with different influencing mechanisms, and adjustments to these parameters under optimization objectives often rely on manual intervention. In other words, there is currently a lack of an integrated optimization method and practical tool for the development and utilization of multiple types of underground thermal energy and their above-ground utilization, which directly impacts the efficient development and utilization of geothermal energy and the practical application of underground thermal storage systems. Summary of the Invention

[0003] The purpose of this invention is to provide an optimized method, apparatus, and electronic device for the development and utilization of geothermal energy, in order to address the current lack of a scientific and reasonable integrated optimization design method for geothermal energy development and above-ground utilization, which directly affects the efficient development and utilization of geothermal energy and the practical application of underground thermal storage systems.

[0004] To achieve the above objectives, embodiments of the present invention provide an optimized method for the development and utilization of geothermal energy, comprising:

[0005] Step S1: Obtain geological data of the target thermal reservoir;

[0006] Step S2: Determine the initial well group mode;

[0007] Step S3: Determine the initial injection-production well spacing;

[0008] Step S4: Based on the geological data, the initial well group pattern, and the initial injection-production well spacing, establish a thermal reservoir-wellbore coupling model of the target thermal reservoir;

[0009] Step S5: Determine the initial production flow rate;

[0010] Step S6: Determine the initial reinjection temperature;

[0011] Step S7: Based on the initial production flow rate and the reinjection temperature, perform transient solution on the thermal reservoir-wellbore coupling model within the target system's operating life to obtain the pressure distribution and temperature distribution of the thermal reservoir-wellbore coupling model;

[0012] Step S8: Based on the temperature distribution, monitor the wellhead temperature of the production well in the thermal reservoir-wellbore coupling model. If the wellhead temperature of the production well in a set year within the target system's operating years does not meet the set temperature threshold, adjust the initial injection-production well spacing and jump to step S3 until the wellhead temperature of the production well in the set year meets the set temperature threshold.

[0013] Step S9: Based on the pressure distribution, monitor the wellhead pressure of the reinjection well in the thermal reservoir-wellbore coupling model. If the wellhead pressure of the reinjection well does not meet the set pressure threshold, adjust the initial production flow rate and jump to step S5 until the wellhead pressure of the reinjection well meets the set pressure threshold.

[0014] Optionally, after step S9, the method further includes:

[0015] Step S10: Determine the user's heat load and the well group's heat recovery power based on the transient solution results of the thermal storage-wellbore coupling model;

[0016] Step S11: Based on the relationship between the user's heat load and the heat extraction power of the well group, determine the next adjustment plan.

[0017] Optionally, step S11, based on the relationship between the user's heat load and the well group's heat extraction power, determines the next adjustment plan, including:

[0018] If the heat extraction power of the well group is greater than the user's heat load, the next adjustment plan is determined to be a multi-stage heat exchange scheme to achieve cascade utilization.

[0019] If the heat extraction power of the well group is less than the user's heat load, and the heat extraction power of the well group is greater than 50% of the user's heat load, the next adjustment plan is determined to be a combination of direct heat exchange and supplementary heat treatment.

[0020] If the heat extraction power of the well group is less than the user's heat load, and the heat extraction power of the well group is less than or equal to 50% of the user's heat load, the initial well group mode is adjusted and the process jumps to step S2 until the heat extraction power of the well group is greater than 50% of the user's heat load.

[0021] Optionally, after step S11, the method further includes:

[0022] Step S12: Based on the next adjustment plan, determine the target functional modules of the ground heat utilization system and optimize their parameters;

[0023] Step S13: Calculate the geothermal tailwater temperature after parameter optimization by the target functional module of the ground heat utilization system. If the absolute value of the difference between the geothermal tailwater temperature and the initial reinjection temperature is greater than or equal to a set threshold, adjust the initial reinjection temperature and jump to step S6 until the absolute value of the difference between the geothermal tailwater temperature and the initial reinjection temperature is less than the set threshold.

[0024] Step S14: Based on the latest initial well group pattern, the initial injection-production well spacing, the initial production flow rate, the initial reinjection temperature, and the next adjustment plan, conduct an economic evaluation of the project;

[0025] Step S15: Automatically generate a project research report based on the results of the project's economic evaluation.

[0026] Optionally, the target functional modules of the ground heat utilization system include at least one of the following: heat exchanger area calculation module, pipeline resistance verification module, system heat loss analysis module, heat pump selection module, and photothermal system coupling module.

[0027] Optionally, the initial well group mode includes any one of the following: one injection and one production mode, one injection and two production mode, and mass production and mass irrigation mode.

[0028] On the other hand, the present invention also provides an optimized device for the development and utilization of underground thermal energy, comprising:

[0029] The acquisition module is used to acquire geological data of the target thermal reservoir;

[0030] The first determining module is used to determine the initial well group pattern;

[0031] The second determining module is used to determine the initial injection-production well spacing;

[0032] The construction module is used to establish a reservoir-wellbore coupling model of the target thermal reservoir based on the geological data, the initial well group pattern, and the initial injection-production well spacing;

[0033] The third determining module is used to determine the initial production flow rate;

[0034] The fourth module is used to determine the initial reinjection temperature;

[0035] The solution module is used to perform transient solution on the thermal reservoir-wellbore coupling model within the target system's operating life based on the initial production flow rate and the reinjection temperature, and to obtain the pressure distribution and temperature distribution of the thermal reservoir-wellbore coupling model.

[0036] The first control module is used to monitor the wellhead temperature of the production well in the thermal reservoir-wellbore coupling model based on the temperature distribution. If the wellhead temperature of the production well in a set year within the target system's operating years does not meet the set temperature threshold, the second determining module, the construction module, the third determining module, the fourth determining module, and the solving module are controlled to execute repeatedly until the wellhead temperature of the production well in the set year meets the set temperature threshold.

[0037] The second control module is used to monitor the wellhead pressure of the reinjection well in the thermal reservoir-wellbore coupling model based on the pressure distribution. If the wellhead pressure of the reinjection well does not meet the set pressure threshold, the second determining module, the construction module, the third determining module, the fourth determining module, the solving module, and the first control module are controlled to repeat execution until the wellhead pressure of the reinjection well meets the set pressure threshold.

[0038] On the other hand, the present invention also provides an electronic device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the program to implement the above-mentioned optimized method for the development and utilization of underground thermal energy.

[0039] On the other hand, the present invention also provides a machine-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the above-mentioned optimized method for the development and utilization of underground thermal energy.

[0040] On the other hand, the present invention also provides a computer program product, including a computer program that, when executed by a processor, implements the above-mentioned optimized method for the development and utilization of underground thermal energy.

[0041] Through the above technical solutions, the embodiments of the present invention realize the optimal logic for optimizing parameters such as the spacing between injection and production wells and the production flow rate in the integrated scheme of above-ground and underground heterogeneous systems. The established optimization method has clear, simple and reliable steps, and realizes the system optimization method for integrating underground heat extraction and above-ground heat use, providing a practical tool for the efficient development and utilization of multiple types of underground thermal energy.

[0042] Other features and advantages of the embodiments of the present invention will be described in detail in the following detailed description section. Attached Figure Description

[0043] The accompanying drawings are provided to further illustrate embodiments of the present invention and form part of the specification. They are used together with the following detailed description to explain the embodiments of the present invention, but do not constitute a limitation thereof. In the drawings:

[0044] Figure 1 This is one of the flowcharts of the optimized method for developing and utilizing underground thermal energy provided by the present invention;

[0045] Figure 2 This is the second flowchart of the optimized method for developing and utilizing underground thermal energy provided by the present invention;

[0046] Figure 3 This is a schematic diagram of the structure of the optimized device for developing and utilizing underground thermal energy provided by the present invention;

[0047] Figure 4 This is a schematic diagram of the structure of the electronic device provided by the present invention. Detailed Implementation

[0048] The specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are for illustration and explanation only and are not intended to limit the scope of the present invention.

[0049] Method Implementation Examples

[0050] Please refer to Figure 1 This invention provides an optimized method for the development and utilization of geothermal energy, comprising:

[0051] Step S1: Obtain geological data of the target thermal reservoir.

[0052] Electronic equipment acquires geological data of the target geothermal reservoir, including geological features, rock physical parameters, and water quality conditions. Geological features primarily describe the formation environment, spatial distribution, and relationship with other geological structures of the target geothermal reservoir. Geological features may include reservoir type (karst fracture type, fracture-pore type, etc.) and geological structures (faults, folds, etc.). Rock physical parameters describe the thermal, mechanical, and electrical properties of the reservoir rocks. Rock physical parameters may include heat capacity, thermal conductivity, density, and sound velocity. Water quality conditions include water chemistry type, salinity, and pH value. Additionally, the electronic equipment can determine wellbore data, including wellbore diameter, material, depth, length and location of filter pipe sections; and fluid data, including temperature, pressure, flow rate, density, and viscosity of injected and produced fluids.

[0053] Step S2: Determine the initial well group mode.

[0054] The initial well group mode includes any one of the following: a one-injection-one-production mode, a one-injection-two-production mode, and a multi-production-multi-irrigation mode. For example, electronic equipment can determine that the initial well group mode is a one-injection-one-production mode.

[0055] Step S3: Determine the initial injection-production well spacing.

[0056] For example, electronic devices can set the initial injection-production well spacing of sandstone thermal reservoirs to 500-600m.

[0057] Step S4: Based on the geological data, the initial well group pattern, and the initial injection-production well spacing, establish a thermal reservoir-wellbore coupling model of the target thermal reservoir.

[0058] The electronic device can construct a three-dimensional geological structure model and attribute model of the target thermal reservoir based on the geological data. Then, based on the three-dimensional geological structure model and attribute model, the seepage and heat transfer processes in the thermal reservoir are considered, including fluid flow, heat conduction, and convection. Appropriate equations are used to describe these processes in the thermal reservoir, such as Darcy's law and Fourier's law of heat conduction, thereby constructing the thermal reservoir model. The electronic device then constructs a development well group model based on the initial well group pattern and the initial injection-production well spacing. Based on the development well group model, the flow characteristics within the wellbore are considered, including pressure loss, heat loss, and fluid phase change (if applicable), and appropriate equations are used to describe the flow and heat transfer processes within the wellbore, thus establishing a wellbore model. Finally, the wellbore model and the thermal reservoir model are coupled to obtain a thermal reservoir-wellbore coupled model of the target thermal reservoir.

[0059] The reservoir-wellbore coupling model is as follows:

[0060] Mass conservation equation within the thermal reservoir:

[0061]

[0062] Where: V,V n Let m be the volume of subregion n. 3 ]; M κ The mass accumulation term of component κ [kg·m -3 ]; Let m be the surface area, and let n be the surface area of ​​subregion n. 2 ];F κ The Darcy flow vector [kg·m] for component κ -2 ·s -1 ]; n is the unit outward normal vector; q κ It is the source and sink term of component κ [kg·m -2 ·s -1 ]; t is time [s].

[0063] The κ component includes:

[0064] κ≡g i Various components i (i = 1, ..., N) in a gas mixture G N G ≥1)

[0065] w water

[0066] The gaseous components include CH4, C2H6, C3H8, and n-C4H. 10 i-C4H10 H2O, CO2, H2S, O2, N2, C2H5OH, and H2.

[0067] The mass accumulation term of component κ is expressed as follows:

[0068]

[0069] Where φ is porosity; ρ α α phase density [kg·m -3 ];S α The α-phase saturation; Let κ be the mass fraction of the α phase [kg / kg]; α represents the possible phase states of the substance component, as follows:

[0070] α≡A aqueous phase (components: liquid water w, N) G Dissolved gas)

[0071] G gas phase (component: N) G Gas, water vapor w)

[0072] Quality transfer items:

[0073]

[0074] In the above formula, the gas mass transfer term

[0075] Source and sink terms in the mass conservation equation:

[0076] Among them, F α This is the mass transfer term for the α phase, where α can be A, representing the liquid phase, or G, representing the gas phase. ρ represents the mass fraction of the κ component in the α phase, φ represents porosity, and ρ represents the mass fraction of the κ component in the α phase. G The density of the gas phase [kg·m -3 ];S G ρ is the gas phase saturation; k is the absolute permeability of the rock [m]. 2 ]; b is the b factor considering the gas slippage effect, k r,G Relative permeability; μ G P is the dynamic viscosity of the gas phase [Pa·s]. G The pressure in the gas phase is [Pa]; g is the acceleration due to gravity [m·s]. -2 ]. It is the diffusion mass flow rate of component κ in the gas phase [kg·m -3 ], It is the molecular diffusion coefficient of multi-component molecules in the gas phase [m 2 ·s -1 ];q αIt is the formation rate of the α phase [kg·m -3 ], This represents the mass fraction of component κ in the gas phase.

[0077] Energy conservation equation within a thermal storage:

[0078]

[0079] Where: V,V n For volume [m 3 ]; M ο The heat accumulation term of the component [J·m- 3 ]; Let m be the surface area, and let n be the surface area of ​​subregion n. 2 ];F ο The thermal Darcy flow vector of the component [J·m -2 ·s -1 ]; n is the unit outward normal vector; q ο It is the heat source sink term of the component [J·m -3 ·s -1 ]; t is time [s].

[0080] Heat accumulation term:

[0081]

[0082] Where, ρ R Density of rock [kg·m -3 ];C R The heat capacity of dry rock [J·kg] -1 ·K -1 ];U α For the sake of the prime minister α Specific internal energy [J·kg -1 When the subscript α is A, U A When α is G, U is the liquid-to-liquid internal energy. G ρ is the specific internal energy of the gas. α α phase density [kg·m -3 ]; T is the reference temperature [K]; φ is the porosity; S α This represents phase saturation.

[0083] Liquid relative internal energy:

[0084] in, This represents the mass fraction of water in the liquid phase. The mass fraction of the gaseous component κ in the liquid phase; N dκ It is the total number of dissolved gas components. and Let κ represent the specific internal energy of water and gas components under p and T conditions, respectively [J·kg].-1 ]. The specific heat of solution of gaseous component κ dissolved in water [J·kg] -1 The reference states for calculating internal energy and enthalpy are p = 101300 Pa and T = 273.15 K.

[0085] Specific internal energy of the gas phase:

[0086] Among them, u G κ The specific internal energy of component κ in the gas phase [J·kg] -1 ], U dep It is the change in internal energy of the gas mixture ratio [J·kg] -1 ]; H G It is the enthalpy of gas mixture [J·kg] -1 ]; P is pressure [Pa], ρ G It is the density of the gas mixture [kg·m -3 ];U G This represents the specific internal energy of the gas phase. This represents the mass fraction of component κ in the gas phase.

[0087] Heat flow term:

[0088]

[0089] Where, λ eff The average thermal conductivity of the rock matrix and the fluid [W·m] -1 ·K -1 ]; H α Specific enthalpy of each phase [J·kg] -1 ];F ο The thermal Darcy flow vector of the component [J·m -2 ·s -1 ]; T is the reference temperature [K].

[0090] The specific enthalpy of the gas phase can be calculated using the following formula:

[0091]

[0092] in, It is the specific enthalpy of component κ in the gas phase [J·kg] -1 ], H dep It is the enthalpy change of gas mixture ratio [J·kg] -1 ]; H G It is the specific enthalpy of the gas phase. The mass fraction of the κ component in the G phase is [kg / kg].

[0093] The specific enthalpy of the liquid phase can be expressed as,

[0094]

[0095] Where, N dκ It is the total number of dissolved gas components. It is the specific enthalpy of each dissolved component in the liquid phase [J·kg]. -1 ], It is the specific enthalpy of solubility of each component in the liquid phase [J·kg]. -1 ], H A It is the specific enthalpy of the liquid phase [J·kg] -1 ], It is the specific enthalpy of the water component in the liquid phase [J·kg]. -1 ], This represents the mass fraction of water in the liquid phase. κ represents the mass fraction of the gaseous component κ in the liquid phase.

[0096] Wellbore calculation model (considering transient heat transfer between the geothermal wellbore and the surrounding formation):

[0097]

[0098] Among them, T f λ represents the fluid temperature inside the wellbore [K]. f Thermal conductivity of the fluid [W·m] -1 ·K -1 ];ρ f fluid density [kg·m -3 ];c f Specific heat capacity of the fluid [J·kg] -1 ·K -1 ]; u is the average velocity of the fluid inside the wellbore [m·s] -1 r0 is the wellbore radius [m]; λ s The average thermal conductivity of the formation in contact with the wellbore [W·m] -1 ·K -1 ];α s The average thermal diffusivity of the formation in contact with the wellbore [m] 2 ·s -1 ]; T s,i Let t be the average formation temperature in contact with the wellbore [K], and t be time [s]. This model is a one-dimensional model along the x-direction of the wellbore length.

[0099] In addition, the electronic equipment sets initial and boundary conditions: initial conditions may include the initial temperature and pressure distribution of the thermal reservoir and wellbore. Boundary conditions may include temperature and pressure conditions at the wellbore wall, and temperature and flow conditions at the thermal reservoir boundary.

[0100] Step S5: Determine the initial production flow rate.

[0101] For example, the electronic device can determine the water yield of a single well under a reasonable drawdown condition as the reasonable production flow of the target geothermal reservoir system according to the pumping test results previously carried out on the target geothermal reservoir system in the area;

[0102] Collect the pumping test results of the geothermal well, and determine the type of relationship curve between water inflow M and drawdown S by adopting the curvature method. The judgment basis is: when n=1, the M-S curve type is linear; when 1<n<2, it is a power function curve; when n=2, it is a parabolic type; when n>2, it is a logarithmic curve type. The pumping test results are organized according to the curve type to obtain the M-S relationship curve, the unknown constants in the relational expression are determined, and then the water inflow of a single well under the water-bearing thickness of the target geothermal reservoir system under the requirement of reasonable water level drawdown in the area is determined.

[0103]

[0104] wherein M1 and M2 are the single well water inflow of a geothermal well corresponding to the working conditions of drawdown S1 and S2 (unit: m) respectively, and the unit is m 3 / d.

[0105] Step S6: Determine the initial reinjection temperature.

[0106] For example, the initial reinjection temperature in the embodiment of the present invention can be any one of 20°C, 30°C and 37°C.

[0107] Step S7: Based on the initial production flow and the reinjection temperature, perform transient solution on the geothermal reservoir-wellbore coupling model within the operation life of the target system to obtain the pressure distribution and temperature distribution of the geothermal reservoir-wellbore coupling model.

[0108] Wherein, the operation life of the target system can be 25 years or 30 years. For the transient solution in the embodiment of the present invention, it is usually necessary to use a numerical method, such as finite difference method (FDM), finite element method (FEM) or finite volume method (FVM), to perform the transient solution, so as to obtain the pressure distribution and temperature distribution of the geothermal reservoir-wellbore coupling model. Transient solution includes the processes of discretizing the model, establishing discrete equations, solving the discrete equations, and obtaining visualization results. In the discretizing the model step, continuous spatial and temporal domains are discretized into grids or nodes. The unknown quantities (such as temperature and pressure) on each grid or node are determined. Establishing discrete equations: discretize the continuous equations into algebraic equations by using a numerical method (such as finite difference method). These equations will describe the temperature and pressure changes at each time step and each grid point. In the solving discrete equations step, an iterative method (such as Newton-Raphson method) or a direct method (such as Gaussian elimination method) is used to solve the discrete equations. The temperature and pressure distribution are updated at each time step. In the visualization results step, visualization tools (such as MATLAB, matplotlib library of Python, etc.) are used to display the pressure and temperature distribution in the geothermal reservoir and the wellbore.

[0109] Step S8: Based on the temperature distribution, monitor the wellhead temperature of the production well in the thermal reservoir-wellbore coupling model. If the wellhead temperature of the production well in a set year within the target system's operating years does not meet the set temperature threshold, adjust the initial injection-production well spacing and jump to step S3 until the wellhead temperature of the production well in the set year meets the set temperature threshold.

[0110] The electronic device monitors the wellhead temperature of the production wells in the thermal reservoir-wellbore coupling model based on the temperature distribution, and determines whether the wellhead temperature meets the heating temperature requirements (set temperature threshold) in the last year of system operation. For example, it determines whether the wellhead temperature of the production wells in the last year of system operation is greater than the set temperature threshold. If not, it returns to step S3, adjusts the initial injection-production well spacing, for example, by reducing the initial injection-production well spacing, and repeats steps S4-S8. The set temperature threshold can be the expected water temperature at the wellhead of the production wells in the last year of system operation, set in advance by the user.

[0111] Step S9: Based on the pressure distribution, monitor the wellhead pressure of the reinjection well in the thermal reservoir-wellbore coupling model. If the wellhead pressure of the reinjection well does not meet the set pressure threshold, adjust the initial production flow rate and jump to step S5 until the wellhead pressure of the reinjection well meets the set pressure threshold.

[0112] The electronic device monitors the wellhead pressure of the reinjection well in the coupled thermal reservoir-wellbore model based on the pressure distribution. It determines whether the wellhead pressure of the reinjection well is reasonable. If the wellhead pressure of the reinjection well is one atmosphere, then atmospheric pressure reinjection is achieved. If it is greater than the user-set pressure threshold, then the initial production flow rate is adjusted, for example, by reducing the initial production flow rate, and the process returns to step S5, repeating steps S6-S9.

[0113] The embodiments of this invention realize the optimal logic for optimizing parameters such as the spacing between injection and production wells and the production flow rate in the integrated scheme of above-ground and underground heterogeneous systems. The established optimization method has clear, simple and reliable steps, and realizes the system optimization method for establishing underground heat extraction and above-ground heat use integration, providing a practical tool for the efficient development and utilization of underground multi-type thermal energy.

[0114] In other aspects of embodiments of the present invention, after step S9, the method further includes:

[0115] Step S10: Determine the user's heat load and the well group's heat recovery power based on the transient solution results of the thermal storage-wellbore coupling model.

[0116] The electronic device can input dynamic curves of user heat load under various scenarios. Specifically, it can input these curves in a list based on weather conditions and the type of radiator at the user end.

[0117] The electronic equipment determines the following formula for calculating the thermal power of the well group based on the transient solution results of the thermal reservoir-wellbore coupling model:

[0118] Q1=M(h fout -h fin )

[0119] Where M is the well group flow rate [kg·s] -1 ]; h fout h fin These are the enthalpy values ​​[J·kg] corresponding to the fluid temperature and pressure at the wellheads of production wells and injection wells, respectively. -1 Q1 represents the heat extraction power of the well group.

[0120] Step S11: Based on the relationship between the user's heat load and the heat extraction power of the well group, determine the next adjustment plan.

[0121] Specifically, step S11, determining the next adjustment plan based on the relationship between the user's heat load and the well group's heat extraction power, includes:

[0122] If the heat extraction power of the well group is greater than the user's heat load, the next adjustment plan is determined to be a multi-stage heat exchange scheme to achieve cascade utilization.

[0123] If the heat extraction power of the well group is less than the user's heat load, and the heat extraction power of the well group is greater than 50% of the user's heat load, the next adjustment plan is determined to be a combination of direct heat exchange and supplementary heat treatment.

[0124] If the heat extraction power of the well group is less than the user's heat load, and the heat extraction power of the well group is less than or equal to 50% of the user's heat load, the initial well group mode is adjusted and the process jumps to step S2 until the heat extraction power of the well group is greater than 50% of the user's heat load.

[0125] The electronic equipment determines whether the well's heat extraction power and the user's heat load are equal. If the well's heat extraction power is greater than the user's heat load, the next adjustment plan is determined to be a multi-stage heat exchange scheme to achieve cascade utilization. For example, high-temperature fluid is extracted from a high-temperature heat source (such as a geothermal well) and transferred to a primary heat-using system (such as a power generation system or a high-temperature heating system) through a primary heat exchanger. After passing through the primary heat exchanger, the temperature of the high-temperature fluid decreases, but it still retains a relatively high thermal energy. The medium-temperature fluid after the primary heat exchanger passes through a secondary heat exchanger, transferring heat to a secondary heat-using system (such as a medium-temperature heating system or a hot water supply system). After passing through the secondary heat exchanger, the temperature of the medium-temperature fluid decreases further, but there is still usable thermal energy. The low-temperature fluid after the secondary heat exchanger passes through a tertiary heat exchanger (or more stages), transferring the remaining heat to a low-temperature heat-using system (such as a low-temperature heating system, recreational therapy, or flower cultivation). Finally, the temperature of the low-temperature fluid drops to a lower level and can be treated through methods such as reinjection.

[0126] If the well group's heat extraction capacity exceeds 50% of the user's heat load, the next adjustment plan will be a combination of direct heat exchange and supplementary heat treatment. For example, direct heat exchange refers to directly transferring underground heat energy to the working fluid (such as water or refrigerant) through an underground heat exchanger (such as a buried pipe heat exchanger), thereby achieving heat extraction and utilization. Supplementary heat treatment methods include gas-fired boilers and solar thermal systems.

[0127] If the heat extraction power of the well group is less than 50% of the user's heat load, the process can return to step S2 to adjust the initial well group mode and number. In one embodiment, the one-injection-one-production mode can be adjusted to the one-injection-two-production mode, and vertical wells can be adjusted to complex modes such as horizontal wells or branch wells.

[0128] The embodiments of this invention realize the optimal logic for optimizing parameters such as injection-production well spacing, well group mode, and production flow rate in the integrated scheme of above-ground and underground heterogeneous systems. The established optimization method has clear, simple, and reliable steps, and realizes the system optimization method for integrating underground heat extraction and above-ground heat use, providing a practical tool for the efficient development and utilization of multiple types of underground thermal energy.

[0129] In other aspects of embodiments of the present invention, after step S11, the method further includes:

[0130] Step S12: Based on the next adjustment plan, optimize the parameters of the target functional modules of the ground heat utilization system. The electronic equipment, according to the heat load, underground heating power, and user-designed standards, determines and selects geothermal energy utilization systems, geothermal energy coupled with solar energy utilization systems, etc., including the design and selection of key equipment parameters. Analysis, etc. The target functional modules of the ground heat utilization system include at least one of the following: a heat exchanger area calculation module, a pipeline resistance verification module, a system heat loss analysis module, a heat pump selection module, and a solar-thermal system coupling module. In this embodiment of the invention, the optimized design of the ground heat utilization system can use particle swarm optimization (PSO) algorithm to find the optimal solution based on optional objectives such as economy and low carbon emissions. Through PSO, key parameters such as geothermal water temperature, flow rate, and heat exchanger temperature difference are automatically optimized.

[0131] Step S13: Calculate the geothermal tailwater temperature after parameter optimization by the target functional module of the ground heat utilization system. If the absolute value of the difference between the geothermal tailwater temperature and the initial reinjection temperature is greater than or equal to a set threshold, adjust the initial reinjection temperature and jump to step S6 until the absolute value of the difference between the geothermal tailwater temperature and the initial reinjection temperature is less than the set threshold.

[0132] The electronic device calculates the temperature of the geothermal tailwater after passing through the ground heat utilization system. If the temperature differs from the initial reinjection temperature in step S6 by more than 20%, that is, the absolute value of the difference between the geothermal tailwater temperature and the initial reinjection temperature is greater than or equal to the set threshold, the system returns to step S6, updates the initial reinjection temperature, and repeats steps S7-S13.

[0133] Step S14: Based on the latest initial well group model, the initial injection-production well spacing, the initial production flow rate, the initial reinjection temperature, and the next adjustment plan, conduct an economic evaluation of the project.

[0134] Step S15: Automatically generate a project research report based on the results of the project's economic evaluation.

[0135] The electronic equipment is comprehensively evaluated based on the latest initial well group model, initial injection-production well spacing, initial production flow rate, initial reinjection temperature, and the construction investment and operating costs of the entire above-ground and underground system after the selection of equipment for the surface heat utilization system. Finally, based on the numerical simulation results, the system automatically generates and exports the research report for the integrated underground thermal energy development and utilization system project.

[0136] Please refer to Figure 2 The following describes a typical embodiment of the present invention:

[0137] Step 1: Obtain information on the geological characteristics, rock physical parameters, and water quality conditions of the target geothermal reservoir;

[0138] Step 2: Preliminary selection of development well group pattern and number;

[0139] Step 3: Preliminary selection of injection-production well spacing;

[0140] Step 4: Establish a three-dimensional geological structure model, attribute model, and development well group model of the target thermal reservoir;

[0141] Step 5: Initially select the production flow rate;

[0142] Step 6: Initial selection of reinjection temperature;

[0143] Step 7: Perform transient solutions on the thermal reservoir-wellbore coupling within the system's operating life to obtain the pressure, temperature distribution, and instantaneous production well temperature storage.

[0144] Step 8: Monitor the wellhead temperature of the production well;

[0145] Step 9: Determine if the wellhead temperature of the production wells meets the heating temperature requirements during the last year of system operation. If not, return to step 3, adjust the well spacing, and repeat steps 4-9.

[0146] Step 10: Monitor the wellhead pressure of the reinjection well;

[0147] Step 11: Determine if the pressure at the wellhead of the reinjection well is reasonable. If the pressure at the wellhead of the reinjection well is one atmosphere, then atmospheric pressure reinjection is achieved. If it is greater than the user-set requirement, return to step 5 and repeat steps 6-11.

[0148] Step 12: Calculate the heat extraction power of the well group;

[0149] Step 13: Calculate the dynamic curves of user heat load under various scenarios;

[0150] Step 14: Determine whether the well group power and the user's heat load are equal. If the well group's heat extraction power is greater than the user's heat load, proceed to step 15. If the well group's heat extraction power is greater than 50% of the user's heat load, proceed to step 16. If the well group's heat extraction power is less than 50% of the user's heat load, return to step 2 and adjust the well group mode and quantity.

[0151] Step 15: Determine the multi-stage heat exchange scheme to achieve cascade utilization;

[0152] Step 16: Determine the scheme as a combination of direct heat exchange and supplemental heat treatment;

[0153] Optional heating methods include gas-fired boilers, solar thermal power, etc.

[0154] Step 17: According to the plan, select the ground heat utilization system, select the corresponding modules and carry out parameter optimization design.

[0155] Step 18: Calculate the temperature of the geothermal tailwater after passing through the ground heat utilization system. If the temperature differs from the reinjection temperature in Step 6 by more than 20%, return to Step 6, update the reinjection temperature, and repeat Steps 7-18.

[0156] Step 19: Conduct an economic evaluation of the project based on the optimized integrated underground and above-ground plan;

[0157] Step 20: Automatically generate the project research report.

[0158] The optimization method for underground thermal energy development and utilization in the basic embodiments of the present invention can establish an integrated system optimization design software for underground heat extraction and above-ground heat use. It is applicable to shallow low-temperature energy development and utilization, hydrothermal geothermal development and utilization, and underground thermal storage system design, and has a user-friendly interface.

[0159] The technical effects of the present invention are as follows:

[0160] (1) The optimal logic for optimizing parameters such as well group mode, well spacing, production flow rate, reinjection temperature and pressure, and surface heat utilization process in the integrated scheme of ground and underground heterogeneous systems has been realized. The optimization method and steps are clear, simple and reliable. It also realizes the optimal matching of the exploitable heat of underground thermal storage and surface heat utilization system, thereby improving the efficiency of geothermal system.

[0161] (2) It solves the problem of lack of practical tools for the efficient development and utilization of various types of underground thermal energy. It establishes an integrated system optimization design software for underground heat extraction and above-ground heat use, which is applicable to the development and utilization of shallow low-temperature energy, hydrothermal geothermal development and utilization, and underground thermal storage system design. The user interface is user-friendly.

[0162] Device Examples

[0163] Please refer to Figure 3 On the other hand, embodiments of the present invention also provide an optimized device for the development and utilization of underground thermal energy, comprising:

[0164] Module 301 is used to acquire geological data of the target thermal reservoir;

[0165] The first determining module 302 is used to determine the initial well group mode;

[0166] The second determining module 303 is used to determine the initial injection-production well spacing;

[0167] Module 304 is used to build a reservoir-wellbore coupling model of the target thermal reservoir based on the geological data, the initial well group pattern and the initial injection-production well spacing;

[0168] The third determining module 305 is used to determine the initial production flow rate;

[0169] The fourth determining module 306 is used to determine the initial reinjection temperature;

[0170] The solver module 307 is used to perform transient solution on the thermal reservoir-wellbore coupling model within the target system's operating life based on the initial production flow rate and the reinjection temperature, so as to obtain the pressure distribution and temperature distribution of the thermal reservoir-wellbore coupling model.

[0171] The first control module 308 is used to monitor the wellhead temperature of the production well in the thermal reservoir-wellbore coupling model based on the temperature distribution. If the wellhead temperature of the production well in a set year within the target system's operating years does not meet the set temperature threshold, the second determining module, the construction module, the third determining module, the fourth determining module, and the solving module are controlled to execute repeatedly until the wellhead temperature of the production well in the set year meets the set temperature threshold.

[0172] The second control module 309 is used to monitor the wellhead pressure of the reinjection well in the thermal reservoir-wellbore coupling model based on the pressure distribution. If the wellhead pressure of the reinjection well does not meet the set pressure threshold, the second determining module, the construction module, the third determining module, the fourth determining module, the solving module, and the first control module are controlled to repeat execution until the wellhead pressure of the reinjection well meets the set pressure threshold.

[0173] Optionally, the device further includes:

[0174] The fifth determining module is used to determine the user's heat load and the well group's heat recovery power based on the transient solution results of the thermal storage-wellbore coupling model;

[0175] The sixth determining module is used to determine the next adjustment plan based on the relationship between the user's heat load and the heat extraction power of the well group.

[0176] Optionally, determining the next adjustment plan based on the relationship between the user's heat load and the well group's heat extraction power includes:

[0177] If the heat extraction power of the well group is greater than the user's heat load, the next adjustment plan is determined to be a multi-stage heat exchange scheme to achieve cascade utilization.

[0178] If the heat extraction power of the well group is less than the user's heat load, and the heat extraction power of the well group is greater than 50% of the user's heat load, the next adjustment plan is determined to be a combination of direct heat exchange and supplementary heat treatment.

[0179] When the heat extraction power of the well group is less than the user's heat load, and the heat extraction power of the well group is less than or equal to 50% of the user's heat load, the first determining module, the second determining module, the third determining module, the fourth determining module, the solving module, the first control module, the second control module, the fifth determining module, and the sixth determining module are controlled to be executed repeatedly until the heat extraction power of the well group is greater than 50% of the user's heat load.

[0180] Optionally, the device further includes:

[0181] The seventh determining module is used to optimize the parameters of the target functional modules of the ground heat utilization system based on the next adjustment plan.

[0182] The third control module is used to calculate the geothermal tailwater temperature after parameter optimization by the target functional module of the ground heat utilization system. If the absolute value of the difference between the geothermal tailwater temperature and the initial reinjection temperature is greater than or equal to a set threshold, the fourth determining module, the solving module, the first control module, the second control module, the fifth determining module, the sixth determining module, and the seventh determining module are controlled to repeat execution until the absolute value of the difference between the geothermal tailwater temperature and the initial reinjection temperature is less than the set threshold.

[0183] The evaluation module is used to conduct an economic evaluation of the project based on the latest initial well group pattern, the initial injection-production well spacing, the initial production flow rate, the initial reinjection temperature, and the next adjustment plan;

[0184] The generation module is used to automatically generate project research reports based on the results of project economic evaluation.

[0185] Optionally, the target functional modules of the ground heat utilization system include at least one of the following: heat exchanger area calculation module, pipeline resistance verification module, system heat loss analysis module, heat pump selection module, and photothermal system coupling module.

[0186] Optionally, the initial well group mode includes any one of the following: one injection and one production mode, one injection and two production mode, and mass production and mass irrigation mode.

[0187] The aforementioned optimization device for developing and utilizing underground thermal energy includes a processor and a memory. The aforementioned acquisition module 301, first determination module 302, second determination module 303, construction module 304, third determination module 305, fourth determination module 306, solution module 307, first control module 308, and second control module 309 are all stored in the memory as program units. The processor executes the aforementioned program units stored in the memory to realize the corresponding functions.

[0188] A processor contains a kernel, which retrieves the corresponding program units from memory. One or more kernels can be configured.

[0189] The memory may include non-permanent memory in computer-readable media, such as random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM, and the memory includes at least one memory chip.

[0190] Figure 4 An example is a schematic diagram of the physical structure of an electronic device, such as... Figure 4 As shown, the electronic device may include: a processor 410, a communication interface 420, a memory 430, and a communication bus 440. The processor 410, communication interface 420, and memory 430 communicate with each other via the communication bus 440. The processor 410 can call logical instructions in the memory 430 to execute an optimization method for the development and utilization of underground thermal energy. This method includes: step S1, acquiring geological data of the target thermal reservoir; step S2, determining the initial well group pattern; step S3, determining the initial injection-production well spacing; step S4, establishing a thermal reservoir-wellbore coupling model of the target thermal reservoir based on the geological data, the initial well group pattern, and the initial injection-production well spacing; step S5, determining the initial production flow rate; step S6, determining the initial reinjection temperature; and step S7, based on the initial production flow rate and the reinjection temperature, performing a transient solution on the thermal reservoir-wellbore coupling model within the target system's operating lifespan to obtain the pressure of the thermal reservoir-wellbore coupling model. Distribution and temperature distribution; Step S8: Based on the temperature distribution, monitor the wellhead temperature of the production well in the thermal reservoir-wellbore coupling model. If the wellhead temperature of the production well in a set year within the target system's operating years does not meet the set temperature threshold, adjust the initial injection-production well spacing and proceed to step S3 until the wellhead temperature of the production well in the set year meets the set temperature threshold; Step S9: Based on the pressure distribution, monitor the wellhead pressure of the reinjection well in the thermal reservoir-wellbore coupling model. If the wellhead pressure of the reinjection well does not meet the set pressure threshold, adjust the initial production flow rate and proceed to step S5 until the wellhead pressure of the reinjection well meets the set pressure threshold.

[0191] Furthermore, the logical instructions in the aforementioned memory 430 can be implemented as software functional units and, when sold or used as independent products, can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present invention, essentially, or the part that contributes to the prior art, or a part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods described in the various embodiments of the present invention. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0192] On the other hand, the present invention also provides a computer program product, which includes a computer program that can be stored on a machine-readable storage medium. When the computer program is executed by a processor, the computer can execute an optimization method for the development and utilization of underground thermal energy. The method includes: step S1, acquiring geological data of the target thermal reservoir; step S2, determining the initial well group pattern; step S3, determining the initial injection-production well spacing; step S4, establishing a thermal reservoir-wellbore coupling model of the target thermal reservoir based on the geological data, the initial well group pattern, and the initial injection-production well spacing; step S5, determining the initial production flow rate; step S6, determining the initial reinjection temperature; and step S7, based on the initial production flow rate and the reinjection temperature, optimizing the thermal reservoir-wellbore coupling model within the target system's operating life. The combined model is used for transient solution to obtain the pressure distribution and temperature distribution of the thermal reservoir-wellbore coupling model; Step S8: Based on the temperature distribution, the wellhead temperature of the production well in the thermal reservoir-wellbore coupling model is monitored. If the wellhead temperature of the production well in a set year within the target system's operating years does not meet the set temperature threshold, the initial injection-production well spacing is adjusted and the process jumps to step S3 until the wellhead temperature of the production well in the set year meets the set temperature threshold; Step S9: Based on the pressure distribution, the wellhead pressure of the reinjection well in the thermal reservoir-wellbore coupling model is monitored. If the wellhead pressure of the reinjection well does not meet the set pressure threshold, the initial production flow rate is adjusted and the process jumps to step S5 until the wellhead pressure of the reinjection well meets the set pressure threshold.

[0193] In another aspect, the present invention also provides a machine-readable storage medium storing a computer program thereon, which, when executed by a processor, implements an optimization method for the development and utilization of underground thermal energy. The method includes: step S1, acquiring geological data of the target thermal reservoir; step S2, determining an initial well group pattern; step S3, determining an initial injection-production well spacing; step S4, establishing a thermal reservoir-wellbore coupling model of the target thermal reservoir based on the geological data, the initial well group pattern, and the initial injection-production well spacing; step S5, determining an initial production flow rate; step S6, determining an initial reinjection temperature; and step S7, based on the initial production flow rate and the reinjection temperature, performing a transient solution on the thermal reservoir-wellbore coupling model within the target system's operating lifespan to obtain the... Pressure and temperature distribution of the reservoir-wellbore coupling model; Step S8: Based on the temperature distribution, monitor the wellhead temperature of the production well in the reservoir-wellbore coupling model. If the wellhead temperature of the production well in a set year within the target system's operating years does not meet the set temperature threshold, adjust the initial injection-production well spacing and proceed to step S3 until the wellhead temperature of the production well in the set year meets the set temperature threshold; Step S9: Based on the pressure distribution, monitor the wellhead pressure of the reinjection well in the reservoir-wellbore coupling model. If the wellhead pressure of the reinjection well does not meet the set pressure threshold, adjust the initial production flow rate and proceed to step S5 until the wellhead pressure of the reinjection well meets the set pressure threshold.

[0194] The device embodiments described above are merely illustrative. The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the modules can be selected to achieve the purpose of this embodiment according to actual needs. Those skilled in the art can understand and implement this without any creative effort.

[0195] Through the above description of the embodiments, those skilled in the art can clearly understand that each embodiment can be implemented by means of software plus necessary general-purpose hardware platforms, and of course, it can also be implemented by hardware. Based on this understanding, the above technical solutions, in essence or the part that contributes to the prior art, can be embodied in the form of a software product. This computer software product can be stored in a computer-readable storage medium, such as ROM / RAM, magnetic disk, optical disk, etc., and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute the methods described in the various embodiments or some parts of the embodiments.

[0196] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, and not to limit them; 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 optimized method for the development and utilization of underground thermal energy, characterized in that, include: Step S1: Obtain geological data of the target thermal reservoir; Step S2: Determine the initial well group mode; Step S3: Determine the initial injection-production well spacing; Step S4: Based on the geological data, the initial well group pattern, and the initial injection-production well spacing, establish a thermal reservoir-wellbore coupling model of the target thermal reservoir; Step S5: Determine the initial production flow rate; Step S6: Determine the initial reinjection temperature; Step S7: Based on the initial production flow rate and the reinjection temperature, perform transient solution on the thermal reservoir-wellbore coupling model within the target system's operating life to obtain the pressure distribution and temperature distribution of the thermal reservoir-wellbore coupling model; Step S8: Based on the temperature distribution, monitor the wellhead temperature of the production well in the thermal reservoir-wellbore coupling model. If the wellhead temperature of the production well in a set year within the target system's operating years does not meet the set temperature threshold, adjust the initial injection-production well spacing and jump to step S3 until the wellhead temperature of the production well in the set year meets the set temperature threshold. Step S9: Based on the pressure distribution, monitor the wellhead pressure of the reinjection well in the thermal reservoir-wellbore coupling model. If the wellhead pressure of the reinjection well does not meet the set pressure threshold, adjust the initial production flow rate and jump to step S5 until the wellhead pressure of the reinjection well meets the set pressure threshold.

2. The optimized method for the development and utilization of geothermal energy according to claim 1, characterized in that, After step S9, the method further includes: Step S10: Determine the user's heat load and the well group's heat recovery power based on the transient solution results of the thermal storage-wellbore coupling model; Step S11: Based on the relationship between the user's heat load and the heat extraction power of the well group, determine the next adjustment plan.

3. The optimized method for the development and utilization of underground thermal energy according to claim 2, characterized in that, Step S11, based on the relationship between the user's heat load and the well group's heat extraction power, determines the next adjustment plan, including: If the heat extraction power of the well group is greater than the user's heat load, the next adjustment plan is determined to be a multi-stage heat exchange scheme to achieve cascade utilization. If the heat extraction power of the well group is less than the user's heat load, and the heat extraction power of the well group is greater than 50% of the user's heat load, the next adjustment plan is determined to be a combination of direct heat exchange and supplementary heat treatment. If the heat extraction power of the well group is less than the user's heat load, and the heat extraction power of the well group is less than or equal to 50% of the user's heat load, the initial well group mode is adjusted and the process jumps to step S2 until the heat extraction power of the well group is greater than 50% of the user's heat load.

4. The optimized method for the development and utilization of geothermal energy according to claim 3, characterized in that, After step S11, the method further includes: Step S12: Based on the next adjustment plan, determine the target functional modules of the ground heat utilization system and optimize their parameters; Step S13: Calculate the geothermal tailwater temperature after parameter optimization by the target functional module of the ground heat utilization system. If the absolute value of the difference between the geothermal tailwater temperature and the initial reinjection temperature is greater than or equal to a set threshold, adjust the initial reinjection temperature and jump to step S6 until the absolute value of the difference between the geothermal tailwater temperature and the initial reinjection temperature is less than the set threshold. Step S14: Based on the latest initial well group pattern, the initial injection-production well spacing, the initial production flow rate, the initial reinjection temperature, and the next adjustment plan, conduct an economic evaluation of the project; Step S15: Automatically generate a project research report based on the results of the project's economic evaluation.

5. The optimized method for the development and utilization of underground thermal energy according to claim 4, characterized in that, The target functional modules of the ground heat utilization system include at least one of the following: heat exchanger area calculation module, pipeline resistance verification module, system heat loss analysis module, heat pump selection module, and photothermal system coupling module.

6. The optimized method for the development and utilization of geothermal energy according to any one of claims 1 to 5, characterized in that, The initial well group mode includes any one of the following: one injection and one production mode, one injection and two production mode, and mass production and mass irrigation mode.

7. An optimized device for the development and utilization of underground thermal energy, characterized in that, include: The acquisition module is used to acquire geological data of the target thermal reservoir; The first determining module is used to determine the initial well group pattern; The second determining module is used to determine the initial injection-production well spacing; The construction module is used to establish a reservoir-wellbore coupling model of the target thermal reservoir based on the geological data, the initial well group pattern, and the initial injection-production well spacing; The third determining module is used to determine the initial production flow rate; The fourth module is used to determine the initial reinjection temperature; The solution module is used to perform transient solution on the thermal reservoir-wellbore coupling model within the target system's operating life based on the initial production flow rate and the reinjection temperature, and to obtain the pressure distribution and temperature distribution of the thermal reservoir-wellbore coupling model. The first control module is used to monitor the wellhead temperature of the production well in the thermal reservoir-wellbore coupling model based on the temperature distribution. If the wellhead temperature of the production well in a set year within the target system's operating years does not meet the set temperature threshold, the second determining module, the construction module, the third determining module, the fourth determining module, and the solving module are controlled to execute repeatedly until the wellhead temperature of the production well in the set year meets the set temperature threshold. The second control module is used to monitor the wellhead pressure of the reinjection well in the thermal reservoir-wellbore coupling model based on the pressure distribution. If the wellhead pressure of the reinjection well does not meet the set pressure threshold, the second determining module, the construction module, the third determining module, the fourth determining module, the solving module, and the first control module are controlled to repeat execution until the wellhead pressure of the reinjection well meets the set pressure threshold.

8. An electronic device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the program, it implements the optimized method for the development and utilization of underground thermal energy as described in any one of claims 1 to 6.

9. A machine-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by the processor, it implements the optimized method for the development and utilization of underground thermal energy as described in any one of claims 1 to 6.

10. A computer program product, comprising a computer program, characterized in that, When the computer program is executed by the processor, it implements the optimized method for the development and utilization of underground thermal energy as described in any one of claims 1 to 6.

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