Underground high-temperature composite fluid heating system

Abstract

The invention relates to the technical field of oil-gas field development and geothermal energy utilization. The invention provides an underground high-temperature composite fluid heating system, which comprises a crude oil separation device, a catalysis module, a high-temperature fluid generation module, an injection well pattern module, a target reservoir and a production well, and is characterized in that the crude oil separation device is communicated with the catalysis module through a first gas inlet pipeline and a second gas inlet pipeline; a first gas outlet pipeline and a second gas outlet pipeline are communicated with a high-temperature fluid generation module, the high-temperature fluid generation module is communicated with an injection well pattern module through a third gas outlet pipeline, the injection well pattern module is communicated with a target reservoir, and the target reservoir supplies energy to the outside through a fourth gas outlet pipeline. And the production well conveys the energy-supplied gas to the heat energy recovery device through the first recovery pipeline. In this way, efficient and uniform heating of the underground reservoir is achieved, energy consumption is reduced while the energy recovery efficiency is improved, and the problems of low heat conduction efficiency and high energy consumption in deep oil gas and hot dry rock development are solved.

Description

Technical Field

[0001] The embodiments of the present invention generally relate to the technical fields of oil and gas field development and geothermal energy utilization, and more particularly to an underground high-temperature composite fluid heating system. Background Art

[0002] Traditional underground reservoir heating technologies, primarily using steam flooding and hot water flooding, suffer from low thermal efficiency, high energy consumption, and uneven heating. In particular, in areas such as shale oil development, heavy oil thermal recovery, and hot dry rock geothermal extraction, conventional heating methods struggle to meet the demands of high-temperature, high-pressure environments.

[0003] Traditionally, a single heat carrier, such as steam, hot water, or supercritical carbon dioxide, is used to thermally stimulate the reservoir. However, such methods have the following significant drawbacks: 1. Inefficient heat transfer and uneven heating: The physical properties of a single heat carrier, such as specific heat capacity and thermal conductivity, have inherent limitations, resulting in insufficient heat transfer rate and thermal diffusion capacity within the reservoir. Particularly in heterogeneous reservoirs, heat carriers can easily flow through high-permeability zones, causing localized overheating in the heated area while underheating other areas, resulting in a phenomenon known as "thermal fingering." This not only reduces energy utilization but can also lead to reservoir stress imbalances or fracture system failure.

[0004] 2. Lack of dynamic monitoring and control: Existing technologies lack the ability to monitor heat carrier migration paths and reservoir temperature fields in real time, making it impossible to dynamically adjust injection parameters such as flow rate, temperature, and phase state. For example, during steam flooding, continuous injection is often conducted without timely detection of steam breakthrough, resulting in wasted heat energy. In geothermal systems, the inability to precisely control the heat exchange zone can lead to a sudden drop in produced fluid temperature. This "blind injection" model results in energy losses as high as 30%-50%.

[0005] 3. Insufficient synergistic utilization of multiple energy sources: Traditional methods often rely on a single energy source, such as gas-fired boilers for heating, and fail to fully utilize complementary energy sources such as geothermal resources or industrial waste heat. Furthermore, chemical compatibility issues between heat carriers and reservoir rocks / fluids, such as scaling and corrosion, further restrict the long-term stability of the system. Summary of the Invention

[0006] To solve the above problems, the present invention achieves efficient and uniform heating of underground reservoirs through innovative composite heat carrier design and intelligent control technology, significantly reducing energy consumption while improving energy recovery rate. It has important promotion and application value and solves the difficult problems of low heat conduction efficiency and high energy consumption in the development of deep oil and gas and hot dry rocks.

[0007] According to an embodiment of the present invention, an underground high-temperature composite fluid heating system is provided. The system comprises: Crude oil separation device: used for separating carbon dioxide and associated gas from crude oil and transporting the carbon dioxide and associated gas to the catalytic module through the first air inlet pipe and the second air inlet pipe; Catalytic module: used for catalyzing the received carbon dioxide and associated gas to generate fluid generating fuel, and transporting the fluid generating fuel to the high-temperature fluid generating module through the first gas outlet pipe and the second gas outlet pipe; High-temperature fluid generation module: used to heat the fluid generation fuel through multiple stages, burn the fluid to produce a composite heat carrier and heated carbon dioxide, and transport the composite heat carrier and heated carbon dioxide to the injection well pattern module through the third outlet pipe; Injection well pattern module: used to inject composite heat carrier and heated carbon dioxide into the target reservoir; Target reservoir: used to store composite heat carrier and heated carbon dioxide, equipped with a reservoir heating module and a distributed temperature sensor array, and supplying energy to the outside through the fourth outlet pipe; Production well: used to transport the gas after energy supply to the heat energy recovery device through the first recovery pipeline, and is equipped with a pressure detection device.

[0008] Furthermore, the crude oil separation device separates carbon dioxide gas and associated gas by membrane separation.

[0009] Furthermore, the catalytic module uses a mixed solvent of ferric sulfate and chromium oxide as a catalyst to carry out the catalytic reaction.

[0010] Furthermore, the high-temperature fluid generation module includes: a multi-stage heating unit, a pressure control unit and a mixing reactor. The multi-stage heating unit uses a combination of electric heating and combustion heating to perform multi-stage heating on the fluid to form supercritical water, high-temperature steam and nanofluid; the multi-stage heating includes a primary electric heating section and a secondary combustion heating section. The pressure control unit controls the system fluid pressure through a multi-stage booster pump and a pressure regulating valve; the mixing reactor mixes supercritical water, high-temperature steam and nanofluid to form a composite heat carrier.

[0011] Furthermore, the injection well network module includes: a multi-branch horizontal well structure in which a main wellbore and several branch wellbores are distributed in a fishbone shape, and an intelligent segmented injection device. The intelligent segmented injection device is connected to the multi-branch horizontal well structure, and the intelligent segmented injection device includes an adjustable throttle valve and a temperature compensator.

[0012] Furthermore, a pressure detection device is provided in the injection well network module. The pressure detection device communicates wirelessly with a distributed temperature sensor array and a central controller. The central controller dynamically adjusts the injection parameters using an adaptive control algorithm based on the analysis results.

[0013] Furthermore, the reservoir heating module includes a thermal conductivity enhancer and a catalyst.

[0014] Furthermore, the heat recovery device is connected to a fluid purification module through a second recovery pipeline for processing the recovered fluid; a carbon capture module is provided in the first recovery pipeline, including a chemical absorption tower and a desorption tower.

[0015] Furthermore, the system also includes a fourth air intake pipeline, which is connected to a vertical well section, which is connected to a horizontal well section, which is connected to a fifth air intake pipeline, and the horizontal well section is set in an underground high-temperature dry hot rock layer. The fifth air intake pipeline inputs carbon dioxide into the target reservoir, and a built-in heating plate is set in the fifth air intake pipeline, and a valve is also provided on the fifth air intake pipeline.

[0016] Furthermore, the fluid purification module is connected to the fourth air intake duct through the third air intake duct.

[0017] The present invention achieves efficient and uniform heating of underground reservoirs through innovative composite heat carrier design and intelligent control technology, significantly reducing energy consumption while improving energy recovery. It has important promotion and application value and solves the problems of low heat conduction efficiency and high energy consumption in the development of deep oil and gas and hot dry rocks.

[0018] It should be understood that the contents described in the summary of the invention are not intended to limit the key or important features of the embodiments of the present invention, nor are they intended to limit the scope of the present invention. Other features of the present invention will become readily understood through the following description.

[0019] Beneficial effects of the present invention: 1. The crude oil separation device is used to separate the carbon dioxide and associated gas from the crude oil. The catalytic module is used to catalyze the separated carbon dioxide and associated gas to generate fuel for the high-temperature fluid generation module. The high-temperature fluid generation module generates a composite heat carrier and heated carbon dioxide gas. That is, the composite heat carrier carries the carbon dioxide gas to flow. The composite heat carrier and heated carbon dioxide are injected into the target reservoir through the injection well pattern module. The gas in the target reservoir is then heated by the reservoir heating module, so that the gas in the target reservoir has high thermal energy, thereby providing clean energy. Through innovative composite heat carrier design and intelligent control technology, efficient and uniform heating of the underground reservoir is achieved, which improves energy recovery while significantly reducing energy consumption, and has important promotion and application value. 2. Through the synergistic effect of four modules—precise generation of high-temperature composite fluids, intelligent injection well patterns, reservoir heating and pressure detection, and distributed temperature sensor arrays—combined with vertical and horizontal well sections, this system achieves efficient heating and in-situ modification of deep oil and gas reservoirs and hot dry rocks, addressing the challenges of low heat conduction efficiency and high energy consumption in the development of deep oil and gas and hot dry rocks. BRIEF DESCRIPTION OF THE DRAWINGS

[0020] The above and other features, advantages and aspects of the embodiments of the present invention will become more apparent with reference to the following detailed description in conjunction with the accompanying drawings, in which: Figure 1 A diagram of an underground high-temperature composite fluid heating system according to an embodiment of the present invention is shown; Figure 2 shows a practical application cross-sectional view according to an embodiment of the present invention; Figure 3 It shows a structural block diagram of a system according to an embodiment of the present invention; Figure 4 A structural block diagram of a monitoring and control module according to an embodiment of the present invention is shown.

[0021] In the figure: 1. Crude oil separation device; 2. Catalytic module; 3. High-temperature fluid generation module; 4. Injection well network module; 5. Target reservoir; 6. Reservoir heating module; 7. Fourth air outlet pipeline; 8. Production well; 9. Distributed temperature sensor array; 10. Pressure monitoring device; 11. Central controller; 12. First recovery pipeline; 13. Heat recovery device; 14. Second recovery pipeline; 15. Fluid purification device; 16. Third air inlet pipeline; 17. Carbon capture module; 18. First air inlet pipeline; 19. Second air inlet pipeline; 20. First air outlet pipeline; 21. Second air outlet pipeline; 22. Third air outlet pipeline; 23. Fourth air inlet pipeline; 24. Vertical well section; 25. Horizontal well section; 26. Fifth air inlet pipeline; 27. Heating plate; 28. Valve. DETAILED DESCRIPTION

[0022] To make the objectives, technical solutions, and advantages of the embodiments of the present invention more clear, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative efforts are within the scope of protection of the present invention.

[0023] According to the implementation mode of the present invention, an underground high-temperature composite fluid heating system is proposed. Through innovative composite heat carrier design and intelligent control technology, efficient and uniform heating of underground reservoirs is achieved, which significantly reduces energy consumption while improving energy recovery rate. It has important promotion and application value and solves the problems of low heat conduction efficiency and high energy consumption in the development of deep oil and gas and hot dry rocks.

[0024] The principles and spirit of the present invention are explained in detail below with reference to several representative embodiments of the present invention.

[0025] Figure 1This is a diagram of an underground high-temperature composite fluid heating system according to an embodiment of the present invention. The system includes: Crude oil separation device 1: used for separating carbon dioxide and associated gas from crude oil and transporting the carbon dioxide and associated gas to the catalytic module through the first air inlet pipe and the second air inlet pipe; Catalytic module: used for catalyzing the received carbon dioxide and associated gas to generate fluid generating fuel, and transporting the fluid generating fuel to the high-temperature fluid generating module through the first gas outlet pipe and the second gas outlet pipe; High-temperature fluid generation module: used to heat the fluid generation fuel through multiple stages, burn the fluid to produce a composite heat carrier and heated carbon dioxide, and transport the composite heat carrier and heated carbon dioxide to the injection well pattern module through the third outlet pipe; Injection well pattern module: used to inject composite heat carrier and heated carbon dioxide into the target reservoir; Target reservoir: used to store composite heat carrier and heated carbon dioxide, equipped with a reservoir heating module and a distributed temperature sensor array, and supplying energy to the outside through the fourth outlet pipe; Production well: used to transport the gas after energy supply to the heat energy recovery device through the first recovery pipeline, and is equipped with a pressure detection device.

[0026] It should be noted that although the operations of the system of the present invention are described in a specific order in the above embodiments and drawings, this does not require or imply that these operations must be performed in this specific order, or that all illustrated operations must be performed to achieve the desired results. Additionally or alternatively, certain steps may be omitted, multiple steps may be combined into one step, and / or one step may be broken down into multiple steps.

[0027] In order to explain the above-mentioned underground high-temperature composite fluid heating system more clearly, two specific embodiments are described below. However, it should be noted that the embodiments are only for better illustrating the present invention and do not constitute an improper limitation to the present invention.

[0028] The following two specific examples further illustrate the underground high-temperature composite fluid heating system in more detail: Example 1: The crude oil separation device 1 is used to separate carbon dioxide and associated gas from crude oil and transport the carbon dioxide and associated gas to the catalytic module 2 through the first air intake pipe 18 and the second air intake pipe 19 .

[0029] The crude oil separation device 1 separates carbon dioxide gas and associated gas by membrane separation.

[0030] Catalytic module 2: used for catalytically reacting the received carbon dioxide and associated gas to generate fluid generating fuel, and transporting the fluid generating fuel to the high-temperature fluid generating module 3 through the first gas outlet pipe 20 and the second gas outlet pipe 21.

[0031] The catalytic module 2 catalyzes the carbon dioxide separated from the crude oil and the associated gas to form a fluid generating fuel. In this embodiment, the catalyst used is a mixed solvent of ferric sulfate and chromium oxide.

[0032] High-temperature fluid generation module 3: used to burn the fluid generating fuel through multi-stage heating gradient heating, intelligent pressure control and supercritical mixing technology in a high-temperature and high-pressure environment to produce a composite heat carrier with a temperature of 450°C and a pressure of 25 MPa and heated carbon dioxide, and transport the composite heat carrier and heated carbon dioxide to the injection well network module 4 through the third outlet pipe 22.

[0033] The high-temperature fluid generation module 3 comprises a multi-stage heating unit, a pressure control unit, and a mixing reactor. The multi-stage heating unit utilizes a combination of electric and combustion heating to heat the fluid in multiple stages, generating supercritical water, high-temperature steam, and nanofluid. Specifically, the multi-stage heating comprises a primary electric heating section at 300°C and a secondary combustion heating section at 450°C. The pressure control unit regulates the system fluid pressure at 25 MPa using a multi-stage booster pump and a pressure-stabilizing valve. The mixing reactor mixes 70% supercritical water, 25% high-temperature steam, and 5% nanofluid to form a composite heat carrier, with the mass fraction of the nanofluid being 0.1%.

[0034] Injection well pattern module 4: Used to inject the composite heat carrier and heated carbon dioxide into the target reservoir 5 at a rate of 300m³ / d. Through the fishbone well pattern layout and dynamic control technology, it solves the problems of traditional injection wells such as "uneven injection, low efficiency, and manual dependence".

[0035] like Figure 1 and Figure 3 As shown, the injection well network module 4 in this embodiment includes: a multi-branch horizontal well structure in which the main wellbore and multiple branch wellbores are distributed in a fishbone shape, and an intelligent segmented injection device. The intelligent segmented injection device is connected to the multi-branch horizontal well structure. The intelligent segmented injection device includes an adjustable throttle valve and a temperature compensator to perform differentiated injection in different sections.

[0036] Through the fishbone well network layout and dynamic control technology, the problems of traditional injection wells such as "uneven injection, low efficiency, and manual dependence" are solved.

[0037] As a preferred embodiment, a pressure monitoring device 10 is provided in the injection well pattern module 4 for real-time monitoring of the airflow pressure in the injection well pattern module 4. The pressure monitoring device 10 collects the pressure every 30 minutes.

[0038] Target reservoir 5: used to store composite heat carrier and heated carbon dioxide, equipped with a reservoir heating module 6 and a distributed temperature sensor array 9, and external energy is supplied through the fourth gas outlet pipe 7. The reservoir heating module 6 controls the temperature of the target reservoir 5 and heats the target reservoir 5 and reduces the viscosity of the crude oil, so that the gas in the target reservoir 5 has higher thermal energy, thereby providing clean energy. The distributed temperature sensor array 9 is used to collect the temperature of the target reservoir 5 in real time. The distributed temperature sensor array 9 collects the temperature every 10 minutes.

[0039] As a preferred embodiment, the reservoir heating module 6 utilizes the efficient thermal conductivity of metal oxide nanoparticles and the directional cracking of acidic / metal catalysts, combined with a mass ratio of 1:0.5-1:2, to achieve the dual goals of precise reservoir temperature control and crude oil viscosity reduction and yield increase. In this example, the catalytic components used are a 1.5% concentration of ZSM-5 molecular sieve (a new zeolite molecular sieve containing organic amine cations) and a 1% concentration of nickel-based catalyst, with a mass ratio of thermal conductivity enhancer to catalytic component of 1:0.5.

[0040] Production well 8: used to transport the energized gas to the heat recovery device 13 through the first recovery pipeline 12. It is equipped with a pressure monitoring device 10 for real-time collection and monitoring of the air flow pressure in the production well 8. The pressure monitoring device 10 collects the pressure every 30 minutes.

[0041] As a preferred embodiment, Figure 4 As shown, the pressure monitoring device 10, the distributed temperature sensor array 9 and a central controller 11 are wirelessly communicated. Through the global perception of the distributed temperature sensor array 9, the real-time warning of the high-precision pressure monitoring device 10 and the intelligent decision-making of the central controller 11, a "perception-analysis-execution" closed-loop system for reservoir development is constructed. The central controller 11 uses an adaptive control algorithm to optimize the injection parameters in real time according to the analysis results, that is, dynamically adjusts the injection parameters based on the monitoring data.

[0042] As a preferred embodiment, a carbon capture module 17 is installed within the first recovery pipeline 12, comprising a chemical absorption tower and a desorption tower, successfully separating the carbon from other gases and fluids in the solution. A heat recovery device 13 is used to recover waste heat from the produced fluid. This device is connected to a fluid purification device 15 via a second recovery pipeline 14, which processes the recovered fluid.

[0043] The carbon capture module 17 is in a stable operating state. The capture efficiency can reach 85% to 90%. The rich liquid is transported to the desorption tower through a pipeline. In the desorption tower, the waste heat recovered by the heat recovery device 13 is used to heat the rich liquid, so that the temperature of the rich liquid is increased. The desorbed high concentration of C After being compressed, dried and processed, the gas is re-injected into the high-temperature fluid generation module 3 through a dedicated pipeline for recycling. The desorbed lean liquid is pumped back to the absorption tower to continue absorbing C .

[0044] In order to further improve the carbon capture efficiency, a high-efficiency filler is set in the absorption tower to increase the gas-liquid contact area and make the absorption reaction more complete. Among them, the high-efficiency filler includes corrugated plate filler and / or wire mesh filler. At the same time, a monitoring feedback system is set in the absorption tower. The monitoring feedback system monitors the temperature, pressure, liquid level and fluid flow rate and other parameters in the absorption tower and desorption tower in real time. According to these parameters, the system can accurately adjust the operating conditions such as the circulation amount and heating temperature of the absorbent, so as to ensure the stable and efficient operation of the carbon capture module 17. It should be understood that the monitoring feedback system in this embodiment can be easily obtained by those skilled in the art based on the existing technology and will not be elaborated here.

[0045] In practical applications, such as Figure 2 As shown in Figure 1, the carbon capture module 17 shows a significant improvement effect. In shale oil development, the captured C Recycling can increase the displacement efficiency of heat carrier by 15% to 20%. This is due to the added C The volume and pressure of the heat carrier are increased, which can better drive the crude oil to flow to the production well 8. In the hot dry rock geothermal mining, the recycled C As a heat carrier, its heat capacity and fluidity are optimized, which can increase the heat extraction efficiency by another 10% to 15%, thereby transferring heat more efficiently.

[0046] The carbon capture module 17 has important environmental and economic value. On the one hand, it significantly reduces the In oil and gas fields or geothermal mining projects, the annual reduction of C On the other hand, it improves the efficiency of resource utilization and reduces production costs. Reduces dependence on external gas sources, saving on purchase and transportation expenses and save costs.

[0047] In this embodiment, in order to ensure the reuse of carbon dioxide and the sufficiency of thermal energy, a fourth air intake pipe 23 is further provided for inputting carbon dioxide from other sources. At the same time, the fourth air intake pipe 23 is connected to the fluid purification device 15 through the third air intake pipe 16 for receiving the carbon dioxide generated by the fluid purification device 15.

[0048] The fourth air intake pipeline 23 inputs the received carbon dioxide into the vertical well section 24 and then enters the fifth air intake pipeline 26 through the horizontal well section 25. The horizontal well section 25 is set in the underground high-temperature dry hot rock layer. The fifth air intake pipeline 26 inputs carbon dioxide into the target reservoir 5. A built-in heating plate 27 is set in the fifth air intake pipeline 26 to perform secondary heating on the gas in the pipeline. A valve 28 is also provided on the fifth air intake pipeline 26.

[0049] Through the above-mentioned heating system and parameter settings, the shale oil recovery rate is 28.1% and the energy consumption is 20%. The shale oil recovery rate of the existing method of using supercritical carbon dioxide as a single heat carrier to thermally stimulate the reservoir is 5.5% and the energy consumption is 48%. It can be clearly seen that the shale oil recovery rate of the heating system of this embodiment is increased by 22.6% and the energy consumption is reduced by 28%.

[0050] Example 2: The crude oil separation device 1 is used to separate carbon dioxide and associated gas from crude oil and transport the carbon dioxide and associated gas to the catalytic module 2 through the first air intake pipe 18 and the second air intake pipe 19 .

[0051] The crude oil separation device 1 separates carbon dioxide gas and associated gas by membrane separation.

[0052] Catalytic module 2: used for catalytically reacting the received carbon dioxide and associated gas to generate fluid generating fuel, and transporting the fluid generating fuel to the high-temperature fluid generating module 3 through the first gas outlet pipe 20 and the second gas outlet pipe 21.

[0053] The catalytic module 2 catalyzes the carbon dioxide separated from the crude oil and the associated gas to form a fluid generating fuel. In this embodiment, the catalyst used is a mixed solvent of ferric sulfate and chromium oxide.

[0054] High-temperature fluid generation module 3: used to burn the fluid generating fuel through multi-stage heating gradient heating, intelligent pressure control and supercritical mixing technology in a high-temperature and high-pressure environment to produce a composite heat carrier with a temperature of 550°C and a pressure of 28 MPa and heated carbon dioxide, and transport the composite heat carrier and heated carbon dioxide to the injection well network module 4 through the third outlet pipe 22.

[0055] The high-temperature fluid generation module 3 comprises a multi-stage heating unit, a pressure control unit, and a mixing reactor. The multi-stage heating unit utilizes a combination of electric and combustion heating to heat the fluid in multiple stages, generating supercritical water, high-temperature steam, and nanofluid. Specifically, the multi-stage heating comprises a primary electric heating section at 250°C and a secondary combustion heating section at 550°C. The pressure control unit regulates the system fluid pressure at 28 MPa using a multi-stage booster pump and a pressure-stabilizing valve. The mixing reactor mixes 80% supercritical water, 15% high-temperature steam, and 5% nanofluid to form a composite heat carrier, with the mass fraction of nanofluid being 3%.

[0056] Injection well pattern module 4: Used to inject the composite heat carrier and heated carbon dioxide into the target reservoir 5 at a rate of 400m³ / d. Through the fishbone well pattern layout and dynamic control technology, it solves the problems of traditional injection wells such as "uneven injection, low efficiency, and manual dependence".

[0057] like Figure 1 and Figure 3 As shown, the injection well network module 4 in this embodiment includes: a multi-branch horizontal well structure in which the main wellbore and multiple branch wellbores are distributed in a fishbone shape, and an intelligent segmented injection device. The intelligent segmented injection device is connected to the multi-branch horizontal well structure. The intelligent segmented injection device includes an adjustable throttle valve and a temperature compensator to perform differentiated injection in different sections.

[0058] Through the fishbone well network layout and dynamic control technology, the problems of traditional injection wells such as "uneven injection, low efficiency, and manual dependence" are solved.

[0059] As a preferred embodiment, a pressure monitoring device 10 is provided in the injection well pattern module 4 for real-time monitoring of the airflow pressure in the injection well pattern module 4. The pressure monitoring device 10 collects the pressure every 20 minutes.

[0060] Target reservoir 5: used to store composite heat carrier and heated carbon dioxide, equipped with a reservoir heating module 6 and a distributed temperature sensor array 9, and supplying energy to the outside through the fourth gas outlet pipe 7. The reservoir heating module 6 controls the temperature and heats the target reservoir 5 and reduces the viscosity of the crude oil, so that the gas in the target reservoir 5 has higher thermal energy, thereby providing clean energy. The distributed temperature sensor array 9 is used to collect the temperature of the target reservoir 5 in real time. The distributed temperature sensor array 9 collects the temperature every 15 minutes.

[0061] As a preferred embodiment, the reservoir heating module 6 achieves the dual goals of precise reservoir temperature control and crude oil viscosity reduction and yield increase by combining the efficient thermal conductivity of metal oxide nanoparticles with the directional cracking of acidic / metal catalysts in a mass ratio of 1:0.5-1:2. In this embodiment, the thermal conductivity enhancer uses copper oxide nanoparticles at a concentration of 3%, and the catalytic components are ZSM-5 molecular sieve at a concentration of 1.5% and a nickel-based catalyst at a concentration of 1%, with a mass ratio of 1:2.

[0062] Production well 8: used to transport the energized gas to the heat recovery device 13 through the first recovery pipeline 12. It is equipped with a pressure monitoring device 10 for real-time collection and monitoring of the air flow pressure in the production well 8. The pressure monitoring device 10 collects the pressure every 20 minutes.

[0063] As a preferred embodiment, Figure 4 As shown, the pressure monitoring device 10, the distributed temperature sensor array 9 and a central controller 11 are wirelessly communicated. Through the global perception of the distributed temperature sensor array 9, the real-time warning of the high-precision pressure monitoring device 10 and the intelligent decision-making of the central controller 11, a "perception-analysis-execution" closed-loop system for reservoir development is constructed. The central controller 11 uses an adaptive control algorithm to optimize the injection parameters in real time according to the analysis results, that is, dynamically adjusts the injection parameters based on the monitoring data.

[0064] As a preferred embodiment, a carbon capture module 17 is installed within the first recovery pipeline 12, comprising a chemical absorption tower and a desorption tower, successfully separating the carbon from other gases and fluids in the solution. A heat recovery device 13 is used to recover waste heat from the produced fluid. This device is connected to a fluid purification device 15 via a second recovery pipeline 14, which processes the recovered fluid.

[0065] The carbon capture module 17 is in a stable operating state. The capture efficiency can reach 85% to 90%. The rich liquid is transported to the desorption tower through a pipeline. In the desorption tower, the waste heat recovered by the heat recovery device 13 is used to heat the rich liquid, so that the temperature of the rich liquid is increased. The desorbed high concentration of C After being compressed, dried and processed, the gas is re-injected into the high-temperature fluid generation module 3 through a dedicated pipeline for recycling. The desorbed lean liquid is pumped back to the absorption tower to continue absorbing C .

[0066] In order to further improve the carbon capture efficiency, a high-efficiency filler is set in the absorption tower to increase the gas-liquid contact area and make the absorption reaction more complete. Among them, the high-efficiency filler includes corrugated plate filler and / or wire mesh filler. At the same time, a monitoring feedback system is set in the absorption tower. The monitoring feedback system monitors the temperature, pressure, liquid level and fluid flow rate and other parameters in the absorption tower and desorption tower in real time. According to these parameters, the system can accurately adjust the operating conditions such as the circulation amount and heating temperature of the absorbent, so as to ensure the stable and efficient operation of the carbon capture module 17. It should be understood that the monitoring feedback system in this embodiment can be easily obtained by those skilled in the art based on the existing technology and will not be elaborated here.

[0067] In practical applications, such as Figure 2 As shown in Figure 1, the carbon capture module 17 shows a significant improvement effect. In shale oil development, the captured C Recycling can increase the displacement efficiency of heat carrier by 15% to 20%. This is due to the added C The volume and pressure of the heat carrier are increased, which can better drive the crude oil to flow to the production well 8. In the hot dry rock geothermal mining, the recycled C As a heat carrier, its heat capacity and fluidity are optimized, which can increase the heat extraction efficiency by another 10% to 15%, thereby transferring heat more efficiently.

[0068] The carbon capture module 17 has important environmental and economic value. On the one hand, it significantly reduces the In oil and gas fields or geothermal mining projects, the annual reduction of C On the other hand, it improves the efficiency of resource utilization and reduces production costs. Reduces dependence on external gas sources, saving on purchase and transportation expenses and save costs.

[0069] In this embodiment, in order to ensure the reuse of carbon dioxide and the sufficiency of thermal energy, a fourth air intake pipe 23 is further provided for inputting carbon dioxide from other sources. At the same time, the fourth air intake pipe 23 is connected to the fluid purification device 15 through the third air intake pipe 16 for receiving the carbon dioxide generated by the fluid purification device 15.

[0070] The fourth air intake pipeline 23 inputs the received carbon dioxide into the vertical well section 24 and then enters the fifth air intake pipeline 26 through the horizontal well section 25. The horizontal well section 25 is set in the underground high-temperature dry hot rock layer. The fifth air intake pipeline 26 inputs carbon dioxide into the target reservoir 5. A built-in heating plate 27 is set in the fifth air intake pipeline 26 to perform secondary heating on the gas in the pipeline. A valve 28 is also provided on the fifth air intake pipeline 26.

[0071] Through the above-mentioned heating system and parameter settings, the shale oil recovery rate is 24%, while the shale oil recovery rate using the existing method of using steam as a single heat carrier to thermally stimulate the reservoir is 8.6%. From this data, it can be seen that the shale oil recovery rate of the heating system of this embodiment is increased by 15.4%, and the operating stability of the heating system of this embodiment is significantly improved.

[0072] Although the spirit and principles of the present invention have been described with reference to several specific embodiments, it should be understood that the present invention is not limited to the specific embodiments disclosed, and the division into various aspects does not mean that the features of these aspects cannot be combined to benefit. Such division is only for the convenience of expression. The present invention is intended to cover various modifications and equivalent arrangements included within the spirit and scope of the appended claims.

[0073] Regarding the limitation of the protection scope of the present invention, those skilled in the art should understand that, based on the technical solution of the present invention, various modifications or variations that can be made by those skilled in the art without creative work are still within the protection scope of the present invention.

Claims

1. An underground high-temperature composite fluid heating system, characterized in that: The system includes: A crude oil separation device (1) is used to separate carbon dioxide and associated gas from crude oil and transport the carbon dioxide and associated gas to the catalytic module (2) through a first air inlet pipe (18) and a second air inlet pipe (19); Catalytic module (2): used for catalytically reacting the received carbon dioxide and associated gas to generate fluid generating fuel, and transporting the fluid generating fuel to the high-temperature fluid generating module (3) through the first gas outlet pipe (20) and the second gas outlet pipe (21); High-temperature fluid generation module (3): used for heating the fluid generation fuel through multiple stages, burning the fluid to generate a composite heat carrier and heated carbon dioxide, and transporting the composite heat carrier and heated carbon dioxide to the injection well pattern module (4) through a third outlet pipe (22); Injection well pattern module (4): used for injecting the composite heat carrier and heated carbon dioxide into the target reservoir (5); Target reservoir (5): used for storing composite heat carrier and heated carbon dioxide, equipped with a reservoir heating module (6) and a distributed temperature sensor array (9), and supplying energy to the outside through a fourth outlet pipe (7); Production well (8): used to transport the gas after energy supply to the heat energy recovery device (13) through the first recovery pipeline (12), and equipped with a pressure monitoring device (10).

2. The underground high-temperature composite fluid heating system according to claim 1, characterized in that: The crude oil separation device (1) separates carbon dioxide gas and associated gas by membrane separation.

3. The underground high-temperature composite fluid heating system according to claim 1, characterized in that: The catalytic module (2) uses a mixed solvent of ferric sulfate and chromium oxide as a catalyst to carry out a catalytic reaction.

4. The underground high-temperature composite fluid heating system according to claim 1, characterized in that: The high-temperature fluid generation module (3) comprises: a multi-stage heating unit, a pressure control unit and a mixing reactor. The multi-stage heating unit uses a combination of electric heating and combustion heating to perform multi-stage heating on the fluid to form supercritical water, high-temperature steam and nanofluid; the multi-stage heating includes a primary electric heating section and a secondary combustion heating section; the pressure control unit controls the system fluid pressure through a multi-stage booster pump and a pressure regulating valve; the mixing reactor mixes the supercritical water, high-temperature steam and nanofluid to form a composite heat carrier.

5. The underground high-temperature composite fluid heating system according to claim 1, characterized in that: The injection well network module (4) comprises: a multi-branch horizontal well structure in which a main wellbore and a plurality of branch wellbores are distributed in a fishbone shape, and an intelligent segmented injection device, wherein the intelligent segmented injection device is connected to the multi-branch horizontal well structure, and the intelligent segmented injection device comprises an adjustable throttle valve and a temperature compensator.

6. The underground high-temperature composite fluid heating system according to claim 1, characterized in that: The injection well network module (4) is provided with a pressure monitoring device (10). The pressure monitoring device (10) is in wireless communication with a distributed temperature sensor array (9) and a central controller (11). The central controller (11) dynamically adjusts the injection parameters using an adaptive control algorithm based on the analysis results.

7. The underground high-temperature composite fluid heating system according to claim 1, characterized in that: The reservoir heating module (6) includes a thermal conductivity enhancer and a catalyst.

8. The underground high-temperature composite fluid heating system according to claim 1, characterized in that: The heat recovery device (13) is connected to a fluid purification device (15) via a second recovery pipe (14) for processing the recovered fluid; a carbon capture module (17) is provided in the first recovery pipe (12), comprising a chemical absorption tower and a desorption tower.

9. The underground high-temperature composite fluid heating system according to claim 1, characterized in that: The system further comprises a fourth air inlet pipeline (23), wherein the fourth air inlet pipeline (23) is connected to a vertical well section (24), the vertical well section (24) is connected to a horizontal well section (25), the horizontal well section (25) is connected to a fifth air inlet pipeline (26), the horizontal well section (25) is arranged in an underground high-temperature dry hot rock layer, the fifth air inlet pipeline (26) inputs carbon dioxide into the target reservoir (5), a built-in heating plate (27) is arranged in the fifth air inlet pipeline (26), and a valve (28) is also arranged on the fifth air inlet pipeline (26).

10. An underground high-temperature composite fluid heating system according to claim 8 or 9, characterized in that: The fluid purification device (15) is connected to the fourth air intake pipe (23) via the third air intake pipe (16).

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