Deep carbonate rock geothermal reservoir mining system

Abstract

The invention provides a deep carbonate rock geothermal reservoir exploitation system, and relates to the technical field of geothermal energy exploitation. By analyzing the physical and mechanical properties of rock, the thermal expansion effect is induced by heat flow injection to generate fractures; the fracture width and the surface area are increased through dissolution of a hydrochloric acid-citric acid solution, and the solution concentration and the injection rate are optimized; thermal conductivity and temperature data of a reservoir are collected, the injection and production well spacing and flow are adjusted in real time, and heat-flow dynamic balance is achieved; a heat insulation layer material is installed on the inner wall of the shaft, the heat conduction coefficient and thickness of the heat insulation layer are optimized by monitoring shaft heat loss data, finally the heat loss control rate is generated to evaluate the heat insulation performance, and efficient and sustainable development of deep carbonate rock geothermal resources is achieved.

Description

Technical Field

[0001] The present invention relates to the technical field of geothermal energy exploitation, and in particular to a deep carbonate geothermal reservoir exploitation system. Background Art

[0002] As a clean, sustainable and renewable energy, geothermal energy has broad prospects for development and utilization. However, there are certain technical difficulties in the exploitation of deep carbonate geothermal reservoirs, including complex physical and mechanical properties of reservoir rocks, difficulty in forming and expanding fracture channels, low thermal efficiency of injection and production systems, and serious heat loss in wellbore. Traditional geothermal reservoir exploitation technology usually cannot fully consider the thermal expansion characteristics and rock dissolution characteristics of the reservoir, resulting in low efficiency of fracture generation and expansion. At the same time, due to the large heat loss of the wellbore during deep well geothermal exploitation, the thermal energy utilization rate of the transmission link decreases, affecting the overall exploitation efficiency. Under high temperature and high ground stress, it is difficult to effectively induce the formation of complex fracture networks, resulting in low reservoir transformation efficiency. In addition, the existing geothermal exploitation methods focus on heat extraction efficiency and ignore the control of wellbore heat loss, resulting in serious heat loss in long-term operation; it is difficult to control the dynamic evolution laws of heat, flow, solid and chemical fields during long-term injection and production, resulting in low resource utilization efficiency. Therefore, how to effectively improve the development of reservoir fractures, improve the heat-flow dynamic balance of the injection and production system, and reduce wellbore heat loss has become a key technical issue in the development of deep carbonate geothermal resources.

[0003] In the prior art, publication number CN118228926A discloses a high-efficiency and intelligent exploitation and reinjection system for medium-deep geothermal wells. Through real-time monitoring data, the geothermal water production capacity evaluation index, geothermal water exploitation effect evaluation index and geothermal water exchange utilization efficiency index are calculated. Based on the comprehensive management coefficient of geothermal water, the geothermal well exploitation and reinjection early warning coefficient is analyzed and compared with the preset value. The effect of geothermal water exploitation and reinjection is comprehensively evaluated from multiple dimensions, so as to more accurately reflect the actual situation of geothermal well exploitation and reinjection.

[0004] The main problems with the above schemes are: the efficient and intelligent mining and reinjection system for medium-deep geothermal wells focuses more on macroscopic real-time monitoring and data analysis, and is mainly used to evaluate the mining and reinjection effects of geothermal water, and is suitable for the overall management of medium-deep geothermal wells. However, it lacks in-depth analysis and optimization methods of the reservoir characteristics, especially the physical and mechanical properties of rocks, and microscopic processes such as fracture generation and expansion; the formation of fracture networks is the key to affecting the efficiency of thermal energy extraction, and the above scheme does not involve specific optimization methods for fracture generation and expansion; it mainly focuses on evaluating and managing mining efficiency, but does not clearly propose specific measures to solve the problem of heat loss in the wellbore; the control methods based on real-time data are relatively macroscopic, and lack the ability to finely control the injection and production flow rate and dynamic pressure drop from the perspective of injection and production balance.

[0005] The above information disclosed in this Background section is only for enhancement of understanding of the background of the present disclosure and therefore it may contain information that does not constitute the prior art that is already known to one of ordinary skill in the art. Summary of the invention

[0006] The object of the present invention is to provide a deep carbonate geothermal reservoir exploitation system to solve the problems raised in the above background technology.

[0007] To achieve the above object, the present invention provides the following technical solutions: A deep carbonate geothermal reservoir mining system, comprising the following specific steps: A rock analysis module is used to obtain deep carbonate reservoir rocks before mining and analyze the physical and mechanical properties of the reservoir rocks, including the elastic modulus, Poisson's ratio and thermal expansion coefficient of the rocks; The fracture generation module is used to inject high-temperature heat flow into the reservoir to cause thermal expansion effect, generate thermal stress to form initial fractures in the reservoir, and calculate the injection intensity of the high-temperature heat flow; The fracture expansion module is used to inject a hydrochloric acid-citric acid composite solution into the initial fracture to dissolve the carbonate rock fracture wall, increase the fracture width and surface area, and obtain the fracture expansion volume and fracture expansion radius in real time, and adjust the solution concentration and solution injection rate according to the change of the fracture expansion volume; The injection-production balance module is used to measure the initial temperature of the reservoir and the outlet temperature of the production well, generate the optimal spacing between the injection and production wells, determine the location of the injection wells, and calculate the injection-production pressure drop. Cold water is injected into the deep carbonate geothermal reservoir through the injection wells, and the injection flow rate is adjusted in real time to make the injection-production pressure drop within the standard pressure drop range. The heat loss calculation module is used to install a multi-layer composite insulation material on the inner wall of the production wellbore to form an insulation layer, obtain the thermal conductivity of the insulation material, measure the length of the production wellbore and the temperature difference between the fluid temperature produced in the production wellbore and the surrounding formation rock, generate the theoretical wellbore heat loss, and collect the production wellbore outlet fluid temperature and the production well inlet fluid temperature to generate the actual heat loss; The heat loss optimization module is used to generate the heat loss control rate based on the theoretical wellbore heat loss and the actual heat loss. According to the size of the heat loss control rate, it is determined whether the thermal conductivity and thickness of the insulation material need to be optimized. Furthermore, the formula for calculating the thermal stress is: ; in, represents thermal stress, represents the thermal expansion coefficient of the reservoir rock, represents the elastic modulus of reservoir rock, represents the injection temperature of the high temperature heat flux, represents the reservoir rock temperature, represents the Poisson's ratio of the reservoir rock; The high-temperature heat flow is water vapor with a temperature higher than the temperature of the reservoir rock; The formula for calculating the injection intensity of high temperature heat flux is: ; in, represents the injection intensity of high temperature heat flux, represents the thermal conductivity of reservoir rock, It represents the penetration radius of high-temperature heat flow, that is, the farthest distance that the injected heat flow can affect in the reservoir.

[0008] Furthermore, the principle for adjusting the solution concentration and the solution injection rate is as follows: Through microseismic monitoring technology, the change curve of the fracture volume and the fracture expansion radius at each moment are obtained in real time. , generating the fracture volume at each moment , expand the radius of the crack at each moment and the target rift expansion radius at each moment Compare and calculate the crack expansion volume at each moment The target crack expansion volume at each moment For comparison, the injection parameters of the solution are adjusted based on the following principles: when When the fracture expansion volume increases too fast, the solution concentration is reduced and the solution injection rate is reduced; when When the fracture expansion volume increases too slowly, the solution concentration is increased and the solution injection rate is accelerated; when When the crack expansion range is insufficient, the solution coverage range is insufficient, and the solution injection rate is accelerated.

[0009] Furthermore, the formula for generating the spacing between injection and production wells is: ; in, represents the optimal spacing between injection and production wells, represents the thermal conductivity of reservoir rock, It represents the difference between the initial temperature of the reservoir and the outlet temperature of the production well. Indicates the baseline injection flow rate.

[0010] Furthermore, the calculation formula of injection-production pressure drop is: ; in, Indicates the injection-production pressure drop, represents the real-time injection flow, that is, the volume of cold water injected into the deep carbonate geothermal reservoir through the injection well per unit time. represents the fluid viscosity of cold water, represents the reservoir fracture height, Represents the width of reservoir fractures.

[0011] Furthermore, the formula for generating the theoretical wellbore heat loss is: ; in, represents the theoretical wellbore heat loss, represents the thermal conductivity of the insulation layer, Indicates the length of the production wellbore. Indicates the fluid temperature in the wellbore of the production well, Indicates the rock temperature of the wellbore wall of the production well, represents the outer radius of the insulation layer, represents the inner radius of the insulation layer; The formula used to generate the actual heat loss is: ; in, Indicates the actual heat loss, represents the fluid mass flow rate of cold water, represents the specific heat capacity of the fluid, represents the fluid temperature at the inlet of the production wellbore, Indicates the fluid temperature at the wellbore outlet of the production well.

[0012] Furthermore, the principle on which the heat loss control rate is generated is: ; in, represents the heat loss control rate; when When the heat insulation layer is too large, choose a material with higher thermal conductivity as the heat insulation layer, and reduce the outer radius of the heat insulation layer or increase the inner radius of the heat insulation layer.

[0013] Compared with the prior art, the present invention has the following beneficial effects: The present invention induces the thermal expansion effect of deep carbonate geothermal reservoir rocks by injecting high-temperature heat flow, generates thermal stress to form initial cracks, avoids the strong disturbance of the formation by high-pressure mechanical equipment, reduces the operating difficulty and equipment cost, and reduces the destructive impact on the reservoir. By adjusting the intensity of the injected heat flow, the formation position and scale of the cracks can be accurately controlled, the directional controllability of the reservoir fracture network can be improved, and the reservoir development efficiency can be improved; the generation of the initial cracks and the subsequent expansion steps directly determine the permeability and heat storage capacity of the reservoir, construct an efficient fracture network, and provide a good flow channel for the subsequent injection and production balance of geothermal fluids.

[0014] The present invention also collects reservoir thermal conductivity and temperature data, and combines real-time monitoring of injection and production flow rates to dynamically adjust the pressure of the injection pump to achieve heat-flow dynamic balance in the injection-production well, effectively avoiding problems such as excessive cooling of the reservoir or excessive pressure loss; in existing geothermal extraction technologies, injection and production flow rates and pressures are usually fixed values, which are difficult to adjust in real time according to dynamic changes in reservoir conditions. The present application calculates injection and production parameters through a dynamic balance formula, and flexibly adjusts the pressure of the injection pump in combination with real-time monitoring data, making the injection and production process more adaptable and accurate; by measuring multiple wellbore parameters and realizing dynamic optimization, it is possible to more accurately control heat loss, and generate a heat loss control rate to determine whether it is necessary to adjust the type and thickness of the insulation material, which can adapt to changes in different geological conditions and wellbore depths, and ensure the efficient operation of deep carbonate geothermal extraction systems in different environments. BRIEF DESCRIPTION OF THE DRAWINGS

[0015] Figure 1 Schematic diagram of system modules according to an embodiment of the present invention. DETAILED DESCRIPTION

[0016] In order to make the objectives, technical solutions and advantages of the present invention more clearly understood, the present invention is further described in detail below in conjunction with specific embodiments.

[0017] It should be noted that, unless otherwise defined, the technical terms or scientific terms used in the present invention should be understood by people with ordinary skills in the field to which the present invention belongs. The words "first", "second" and similar words used in the present invention do not indicate any order, quantity or importance, but are only used to distinguish different components. "Include" or "comprise" and similar words mean that the elements or objects appearing before the word include the elements or objects listed after the word and their equivalents, without excluding other elements or objects. "Connect" or "connected" and similar words are not limited to physical or mechanical connections, but may include electrical connections, whether direct or indirect. "Up", "down", "left", "right" and the like are only used to indicate relative positional relationships. When the absolute position of the described object changes, the relative positional relationship may also change accordingly.

[0018] Example: See also Figure 1 , the present invention provides a technical solution: A deep carbonate geothermal storage and mining system, comprising the following specific steps: A rock analysis module is used to obtain deep carbonate reservoir rocks before mining and analyze the physical and mechanical properties of the reservoir rocks, including the elastic modulus, Poisson's ratio and thermal expansion coefficient of the rocks; In this embodiment, the principle of obtaining deep carbonate reservoir rocks is: Drilling with a coring drill bit to obtain complete reservoir rock samples from the geothermal reservoir, and measuring the compressive strength and elastic modulus of the reservoir rock samples through uniaxial compression tests; simulating the ground stress conditions deep in the reservoir through triaxial compression tests to test the Poisson's ratio of the reservoir rock samples; and measuring the thermal expansion coefficient of the reservoir rock samples through a thermal expansion instrument; The elastic modulus and Poisson's ratio of rock determine the degree of deformation of rock under stress and are used to predict the scale and shape of reservoir cracks under external stimulation. The main mechanism of heat flow-induced cracks is the thermal expansion effect. The thermal expansion coefficient of reservoir rock determines the impact of temperature changes on the stress distribution of rock, thereby affecting the efficiency of crack generation.

[0019] The fracture generation module is used to inject high-temperature heat flow into the reservoir to cause thermal expansion effect, generate thermal stress to form initial fractures in the reservoir, and calculate the injection intensity of the high-temperature heat flow; In this embodiment, the formula for generating thermal stress is: ; in, represents thermal stress, represents the thermal expansion coefficient of the reservoir rock, represents the elastic modulus of reservoir rock, represents the injection temperature of the high temperature heat flux, represents the reservoir rock temperature, represents the Poisson's ratio of the reservoir rock; The formula for calculating the injection intensity of high temperature heat flux is: ; in, represents the injection intensity of high temperature heat flux, represents the thermal conductivity of reservoir rock, It represents the penetration radius of high-temperature heat flow, that is, the farthest distance that high-temperature heat flow can affect in the reservoir.

[0020] The high-temperature heat flow refers to water vapor with a temperature higher than the temperature of the reservoir rock. The purpose of generating the high-temperature heat flow injection intensity is to accurately induce the formation and initial expansion of cracks by controlling thermal stress. The reservoir rock has a certain tensile strength. Only when the tensile stress applied by the outside world, which is thermal stress in this scheme, exceeds the tensile strength, will the rock break and form cracks. When the temperature of the injected high-temperature heat flow is When the temperature is higher than the reservoir rock temperature, thermal stress is generated, and The higher the value, the greater the thermal stress, the faster the rate of initial crack generation, and the larger the crack volume; the penetration radius of high-temperature heat flow It reflects the range of thermal stress on reservoir rocks, that is, the distance range over which high-temperature heat flow can be effectively transmitted and produce thermal expansion effect on rocks. The penetration radius of heat flow is calculated based on the heat conduction theory, and the formula is: ; ; in, represents the penetration radius of high-temperature heat flow, Indicates the high temperature heat flow action time, represents the thermal diffusivity of the reservoir rock, represents the density of reservoir rock, Represents the specific heat capacity of reservoir rock.

[0021] The fracture expansion module is used to inject a hydrochloric acid-citric acid composite solution into the initial fracture to dissolve the carbonate rock fracture wall, increase the fracture width and surface area, and obtain the fracture expansion volume and fracture expansion radius in real time, and adjust the solution concentration and solution injection rate according to the change of the fracture expansion volume; In this embodiment, the fracture expansion volume represents the difference between the real-time fracture volume after the composite solution is injected and the initial fracture volume of the reservoir, and the fracture expansion radius represents the difference between the real-time fracture radius after the composite solution is injected and the initial fracture radius of the reservoir; the ultimate goal is to make the actual fracture volume As close as possible to the designed target fracture volume ; It indicates the dissolution rate of a solution into rock, which is mainly related to the concentration of the solution. The higher the concentration of the solution, the faster the dissolution rate.

[0022] The principles for adjusting solution concentration and solution injection rate are as follows: Through microseismic monitoring technology, the change curve of the fracture volume and the fracture expansion radius at each moment are obtained in real time. , generating the fracture volume at each moment , expand the radius of the crack at each moment and the target rift expansion radius at each moment Compare and calculate the crack expansion volume at each moment The target crack expansion volume at each moment For comparison, the injection parameters of the solution are adjusted based on the following principles: when When the fracture expansion volume increases too fast, the solution concentration is reduced and the solution injection rate is reduced; when When the fracture expansion volume increases too slowly, the solution concentration is increased and the solution injection rate is accelerated; when When the crack expansion range is insufficient, the solution coverage range is insufficient, and the solution injection rate is accelerated.

[0023] The injection-production balance module is used to measure the initial temperature of the reservoir and the outlet temperature of the production well, generate the optimal spacing between the injection and production wells, determine the location of the injection wells, and calculate the injection-production pressure drop. Cold water is injected into the deep carbonate geothermal reservoir through the injection wells, and the injection flow rate is adjusted in real time to make the injection-production pressure drop within the standard pressure drop range. In this embodiment, the formula for generating the spacing between injection and production wells is: ; in, represents the optimal spacing between injection and production wells, represents the thermal conductivity of reservoir rock, It represents the difference between the initial temperature of the reservoir and the outlet temperature of the production well. Indicates the baseline injection flow rate.

[0024] The purpose of this embodiment is to determine the distance between the injection well and the production well based on known parameters such as the production well outlet temperature, so that the distance between the injection and production wells can meet the heat exchange process of maintaining a stable reservoir and fully utilize the reservoir heat, thereby determining the location of the injection well.

[0025] The purpose of optimizing the spacing between injection and production wells is to ensure full utilization of geothermal resources while avoiding premature thermal breakthrough, that is, the injected cold water directly penetrates into the production wells, resulting in the inability to effectively extract geothermal energy.

[0026] The higher the thermal conductivity of the reservoir rock, the higher the efficiency of heat transfer in the geothermal reservoir. When cold water flows through the reservoir fractures, it can absorb the heat in the rock more quickly, so the distance required to achieve the target temperature difference is shorter. That is, when the thermal conductivity is high, the heat propagation range is wide and the speed is fast, so a smaller injection-production well spacing is selected. When the thermal conductivity is low, the heat flow propagation range is small, and cold water needs a longer path to absorb enough heat, so a larger injection-production well spacing is selected. The distance between injection and production wells directly affects the retention time of cold water in the reservoir. The amount of heat absorbed by the fluid is proportional to the retention time. When the temperature difference requirement is high, a larger distance between injection and production wells is required so that the cold water can repeatedly absorb heat. When the temperature difference requirement is low, a smaller distance between injection and production wells is designed. The larger the injection flow rate, the faster the cold water spreads in the reservoir, which means that the cold water needs a shorter distance to reach the production well. The larger the injection flow rate, the faster the injected fluid moves, and a smaller injection-production well spacing is required to maintain a stable heat exchange process; the smaller the injection flow rate, the slower the injected fluid moves, and a larger injection-production well spacing is required to fully utilize the reservoir heat.

[0027] The calculation formula for injection-production pressure drop is: ; in, Indicates the injection-production pressure drop, represents the real-time injection flow, that is, the volume of cold water injected into the deep carbonate geothermal reservoir through the injection well per unit time. represents the fluid viscosity of cold water, represents the reservoir fracture height, Represents the width of reservoir fractures.

[0028] The dynamic balance formula reflects the pressure loss of the injected fluid when it flows in the reservoir. Too much pressure drop may cause the reservoir fractures to be destroyed, while too little pressure drop may lead to insufficient fluid flow and low heat exchange efficiency. The injection flow rate of the injection-production system is dynamically adjusted according to the calculation results of the pressure drop. , ensure that the pressure gradient and heat flow distribution in the reservoir are balanced, avoid thermal breakthrough or fluid waste, when the injection-production pressure drop is too large, reduce the injection flow rate, when the injection-production pressure drop is too small, increase the injection flow rate.

[0029] The standard pressure drop range represents a reasonable range of the pressure difference between the injection well and the production well, which needs to take into account both formation stability and fluid circulation efficiency, and the specific value is usually 5 to 15 MPa.

[0030] The heat loss calculation module is used to install a multi-layer composite insulation material on the inner wall of the production wellbore to form an insulation layer, obtain the thermal conductivity of the insulation material, measure the length of the production wellbore and the temperature difference between the fluid temperature produced in the production wellbore and the surrounding formation rock, generate the theoretical wellbore heat loss, and collect the production wellbore outlet fluid temperature and the production well inlet fluid temperature to generate the actual heat loss; In this embodiment, the formula for generating the theoretical wellbore heat loss is: ; in, represents the theoretical wellbore heat loss, represents the thermal conductivity of the insulation layer, Indicates the length of the production wellbore. Indicates the fluid temperature in the wellbore of the production well, Indicates the rock temperature of the wellbore wall of the production well, represents the outer radius of the insulation layer, represents the inner radius of the insulation layer; The formula used to generate the actual heat loss is: ; in, Indicates the actual heat loss, represents the fluid mass flow rate of cold water, represents the specific heat capacity of the fluid, represents the fluid temperature at the inlet of the production wellbore, Indicates the fluid temperature at the wellbore outlet of the production well.

[0031] The theoretical wellbore heat loss reflects the theoretical heat loss of the produced fluid in the insulation layer of the wellbore under the designed insulation structure, that is, only considering the heat conduction loss in the wellbore of the production well and ignoring the external influence; the actual heat loss represents the actual temperature loss between the inlet and outlet of the wellbore of the production well, that is, the heat loss of the produced fluid in the process of flowing in and out of the production well.

[0032] The heat loss optimization module is used to generate the heat loss control rate based on the theoretical wellbore heat loss formula and the actual heat loss, and to determine whether the thermal conductivity and thickness of the insulation material need to be optimized according to the size of the heat loss control rate.

[0033] In this embodiment, the principle for generating the heat loss control rate is: ; in, Represents the heat loss control rate.

[0034] The heat loss control rate reflects the difference between actual heat loss and theoretical heat loss. The closer the value is to 1, the closer the insulation is to the ideal state and the more effective the heat loss control is. , indicating that the actual heat loss is higher than the theoretical heat loss, and it is necessary to re-optimize, select a material with higher thermal conductivity as the insulation layer, and reduce the outer radius of the insulation layer or increase the inner radius of the insulation layer.

[0035] The above formulas are all dimensionless and numerical calculations. The formula is a formula for the most recent real situation obtained by collecting a large amount of data and performing software simulation. The preset parameters in the formula are set by technicians in this field according to actual conditions.

[0036] The above embodiments may be implemented in whole or in part by software, hardware, firmware or any other combination thereof. When implemented by software, the above embodiments may be implemented in whole or in part in the form of a computer program product. Those skilled in the art may appreciate that the units and algorithm steps of each example described in conjunction with the embodiments disclosed herein may be implemented by electronic hardware, or a combination of computer software and electronic hardware. Whether these functions are performed by hardware or software methods depends on the specific application and design constraints of the technical solution.

[0037] The units described as separate components may or may not be physically separated, and the components shown as units may or may not be physical units, and may be located in one place or distributed on multiple network units. Some or all of the units may be selected according to actual needs to achieve the purpose of the solution of this embodiment.

[0038] The above description is only a specific implementation manner of the present application, but the protection scope of the present application is not limited thereto. Any technician familiar with the technical field can easily think of changes or substitutions within the technical scope disclosed in the present application, which should be included in the protection scope of the present application.

Claims

1. A deep carbonate geothermal reservoir mining system, characterized in that: Specifically include: A rock analysis module is used to obtain deep carbonate reservoir rocks before mining and analyze the physical and mechanical properties of the reservoir rocks, including the elastic modulus, Poisson's ratio and thermal expansion coefficient of the rocks; The fracture generation module is used to inject high-temperature heat flow into the reservoir to cause thermal expansion effect, generate thermal stress to form initial fractures in the reservoir, and calculate the injection intensity of the high-temperature heat flow; The fracture expansion module is used to inject a hydrochloric acid-citric acid composite solution into the initial fracture to dissolve the carbonate rock fracture wall, increase the fracture width and surface area, and obtain the fracture expansion volume and fracture expansion radius in real time, and adjust the solution concentration and solution injection rate according to the change of the fracture expansion volume; The injection-production balance module is used to measure the initial temperature of the reservoir and the outlet temperature of the production well, generate the optimal spacing between the injection and production wells, determine the location of the injection wells, and calculate the injection-production pressure drop. Cold water is injected into the deep carbonate geothermal reservoir through the injection wells, and the injection flow rate is adjusted in real time to make the injection-production pressure drop within the standard pressure drop range. The heat loss calculation module is used to install a multi-layer composite insulation material on the inner wall of the production wellbore to form an insulation layer, obtain the thermal conductivity of the insulation material, measure the length of the production wellbore and the temperature difference between the fluid temperature produced in the production wellbore and the surrounding formation rock, generate the theoretical wellbore heat loss, and collect the production wellbore outlet fluid temperature and the production well inlet fluid temperature to generate the actual heat loss; The heat loss optimization module is used to generate a heat loss control rate based on theoretical wellbore heat loss and actual heat loss, and to determine whether the thermal conductivity and thickness of the insulation material need to be optimized according to the size of the heat loss control rate.

2. A deep carbonate geothermal reservoir exploitation system according to claim 1, characterized in that: The formula for calculating thermal stress in the crack generation module is: ； in, represents thermal stress, represents the thermal expansion coefficient of the reservoir rock, represents the elastic modulus of reservoir rock, represents the injection temperature of the high temperature heat flux, represents the reservoir rock temperature, represents the Poisson's ratio of the reservoir rock; The high-temperature heat flow is water vapor with a temperature higher than the temperature of the reservoir rock; The formula for calculating the injection intensity of high temperature heat flux is: ； in, represents the injection intensity of high temperature heat flux, represents the thermal conductivity of reservoir rock, It represents the penetration radius of high-temperature heat flow, that is, the farthest distance that the injected heat flow can affect in the reservoir.

3. A deep carbonate geothermal reservoir exploitation system according to claim 1, characterized in that: The principles for adjusting solution concentration and solution injection rate are as follows: Through microseismic monitoring technology, the change curve of the fracture volume and the fracture expansion radius at each moment are obtained in real time. , generating the fracture volume at each moment , expand the radius of the crack at each moment and the target rift expansion radius at each moment Compare and calculate the crack expansion volume at each moment The target crack expansion volume at each moment For comparison, the injection parameters of the solution are adjusted based on the following principles: when When the fracture expansion volume increases too fast, the solution concentration is reduced and the solution injection rate is reduced; when When the crack expansion volume increases too slowly, the solution concentration is increased and the solution injection rate is accelerated; when When the crack expansion range is insufficient, the solution coverage range is insufficient, and the solution injection rate is accelerated.

4. A deep carbonate geothermal reservoir exploitation system according to claim 1, characterized in that: The formula for generating the spacing between injection and production wells in the injection-production balance module is: ； in, represents the optimal spacing between injection and production wells, represents the thermal conductivity of reservoir rock, It represents the difference between the initial temperature of the reservoir and the outlet temperature of the production well. Indicates the baseline injection flow rate.

5. A deep carbonate geothermal reservoir exploitation system according to claim 4, characterized in that: The calculation formula of the injection-production pressure drop in the injection-production balance module is: ； in, Indicates the injection-production pressure drop, represents the real-time injection flow, that is, the volume of cold water injected into the deep carbonate geothermal reservoir through the injection well per unit time. represents the fluid viscosity of cold water, represents the reservoir fracture height, Represents the width of reservoir fractures.

6. A deep carbonate geothermal reservoir exploitation system according to claim 1, characterized in that: The formula for generating the theoretical wellbore heat loss in the heat loss calculation module is: ； in, represents the theoretical wellbore heat loss, represents the thermal conductivity of the insulation layer, Indicates the length of the production wellbore. Indicates the fluid temperature in the wellbore of the production well, Indicates the rock temperature of the wellbore wall of the production well, represents the outer radius of the insulation layer, represents the inner radius of the insulation layer; The formula used to generate the actual heat loss is: ； in, Indicates the actual heat loss, represents the fluid mass flow rate of cold water, represents the specific heat capacity of the fluid, represents the fluid temperature at the inlet of the production wellbore, Indicates the fluid temperature at the wellbore outlet of the production well.

7. A deep carbonate geothermal reservoir exploitation system according to claim 6, characterized in that: The principle for generating the heat loss control rate in the heat loss optimization module is: ； in, represents the heat loss control rate; when When the heat insulation layer is too large, choose a material with higher thermal conductivity as the heat insulation layer, and reduce the outer radius of the heat insulation layer or increase the inner radius of the heat insulation layer.

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