Unconventional energy in-situ oil-gas production and modification-waste heat utilization-carbon storage combined production method

Abstract

Belongs to the technical field of unconventional energy in-situ exploitation, and particularly relates to an unconventional energy in-situ oil-gas production and modification-waste heat utilization-carbon storage combined exploitation method which comprises an in-situ oil-gas production and modification stage, a hydrogen production or heat generation stage, a stratum waste heat recovery stage and a CO2 storage stage. The energy return maximization is realized; the method comprises the steps that firstly, oxygen-containing gas is used for preheating a stratum, a self-heat-generation reaction is triggered, different chemical reaction areas are formed, normal-temperature water is injected into the self-heat-generation and cracking areas, oil and gas migration is displaced, and generation of light oil is promoted; after the oil gas is cracked, in-situ hydrogen production is achieved through gasification reaction of carbon residues and water and water gas reaction, or in-situ heat generation is achieved through oxidation exothermic reaction of the carbon residues and oxygen, and in-situ heat collection is achieved through circulation of CO2 in the stratum; and finally, the CO2 is sealed in the in-situ reservoir. According to the method, unconventional energy in-situ oil and gas extraction and modification, energy recovery maximization and green low-carbon exploitation are achieved.

Description

Technical Field

[0001] The present invention belongs to the technical field of unconventional energy in-situ mining, and in particular relates to an unconventional energy in-situ oil and gas production and upgrading-waste heat utilization-carbon storage joint mining method. Background Art

[0002] The extraction of unconventional oil and gas energy requires heating solid organic matter to a certain temperature, cracking it to produce oil and gas products. Among these, autogenous thermal in-situ conversion technology has attracted widespread attention in the industry due to its low energy consumption and high yield. This technology utilizes the heat released by the oxidation of oxygen and residual carbon to provide energy for the cracking of kerogen to produce oil and gas, forming an autogenous thermal chain reaction. A pilot in-situ test of autogenous thermal technology in oil shale has been completed and successfully produced oil, demonstrating its feasibility.

[0003] However, heavy components generated by kerogen cracking are prone to coking during in-situ conversion and migration, which in turn clogs pores and reduces oil and gas yields. Among existing in-situ conversion technologies, the autogenous thermal in-situ conversion method for low- to medium-maturity, organic-rich shales (CN114017032B) proposes preheating the formation with high-temperature air, then injecting ambient-temperature air to react with residual carbon to trigger an autogenous thermal chain reaction and define chemical reaction zones. However, this method does not provide an effective solution for the migration of heavy components. A system and method for underground in-situ pyrolysis of oil shale for oil and gas upgrading (CN118065850B) proposes using heat generated by the reaction of high-temperature supercritical water, CO, and water to heat the oil shale and produce oil and gas products. This method provides active hydrogen, thereby suppressing the coking reaction of heavy components. However, the formation of high-temperature supercritical water requires a certain pressure, limiting its applicability to certain formations.

[0004] In addition, after the in-situ autogenous thermal cracking of oil shale is completed, the formation temperature is still at a high temperature. The current utilization of waste heat is not effective, resulting in heat waste. Patent CN115405276B proposes to use high-temperature steam to heat the first plot, and use the flue gas after the combustion of cracking gas, high-temperature steam and the waste heat of the previous formation to heat the subsequent plots. This method does not provide a solution for the utilization of waste heat in this block. At the same time, high-temperature steam is generated on the ground, and the injection process causes serious heat loss along the way. In fact, a large amount of residual carbon remains in the formation after autogenous thermal cracking. On the one hand, the residual carbon can continue to react with water, providing good reaction conditions for in-situ hydrogen production; on the other hand, it can continue to undergo oxidation reaction with oxygen to generate a large amount of heat, which can be recycled and reused.

[0005] Therefore, exploring a feasible technology for comprehensive utilization of unconventional energy such as in-situ oil and gas production and upgrading, waste heat utilization and CO2 storage is of great significance to promoting the commercialization and clean development of unconventional energy such as oil shale. Summary of the Invention

[0006] The purpose of the present invention is to solve the problems existing in the above-mentioned background technology, and to provide a method for comprehensive mining of unconventional energy in situ oil and gas production improvement, quality improvement, waste heat utilization and carbon storage, which realizes the maximization of energy return by the coordinated phased mining of unconventional energy through water and oxygen. The method preheats the formation by oxygen-containing gas, triggers the autogenous heat reaction and forms an autogenous heat chemical reaction area, injects room temperature water into the cracking area, displaces the migration of oil and gas and promotes the generation of light oil, and after the cracking is completed, the gasification reaction and water-gas reaction between the residual carbon and water can be used to realize in-situ hydrogen production or the exothermic oxidation reaction between the residual carbon and oxygen can be used to realize in-situ heat generation, and then the CO2 is injected into the formation by circulation to realize in-situ heat recovery, and finally the CO2 is sealed in the in-situ reservoir. The method can realize the efficient extraction of unconventional energy oil and gas, maximum energy recovery and green and low-carbon mining.

[0007] A method for in-situ oil and gas production and upgrading, waste heat utilization, and carbon storage and joint production of unconventional energy, the method specifically comprising the following steps:

[0008] Step 1: Drill at least one heating well and one production well in the mining area to the target reservoir. When the formation heat is used for in-situ hydrogen production, drill at least one horizontal well with a vertical section close to the heating well. After casing is run, the entire well section is cemented, and the target reservoir is staged fractured to form a fracture seepage channel between the heating well and the production well.

[0009] Step 2: Lower a downhole heater into the heating well. After the oxygen-containing gas is heated, it convectively heats the target reservoir. The exothermic oxidation reaction of oxygen and part of the oil and gas products triggers a self-heating chain reaction and forms different chemical reaction areas between the heating well and the production well. An appropriate amount of room-temperature water is injected into the target reservoir to displace oil and gas migration and increase the oil and gas yield. After the oil and gas are pumped to the ground, they are heat-exchanged with the room-temperature oxygen-containing gas in a heat exchanger and then enter the gas-liquid separation device and the oil-water separation device for separation. The cracked oil is stored in an oil storage tank. The oxygen-containing gas, cracked gas, and water that have been heated initially are re-injected into the target reservoir. The above heating process is repeated until the oil and gas products are completely produced.

[0010] Step three: Continue to inject room-temperature oxygen-containing gas into the heating well. When the formation heat is used for in-situ hydrogen production, a water-soluble catalytic solution is directionally injected into the formation through a horizontal well. Under high-temperature catalytic conditions, water reacts with residual carbon and CO to generate CO2 and H2. After being extracted to the ground and separated, H2 is stored in a gas tank and CO2 is reinjected into the underground. The above operation is repeated until the reaction is completed. When the formation heat is used for in-situ heat extraction, water is no longer injected into the formation. Oxygen and residual carbon are oxidized to release heat to generate a large amount of heat and CO2. The high-temperature CO2 is re-injected into the formation after heat exchange on the ground.

[0011] Step 4: After the carbon residue has completed the reaction, supercritical CO2 is circulated in the target reservoir to recover the heat from the high-temperature formation.

[0012] Step 5: When the target reservoir temperature drops to 100°C, close the heating well or production well, and inject the CO2 generated by cracking and industrial capture into the target reservoir in a supercritical state for underground CO2 storage.

[0013] Furthermore, the unconventional energy sources are oil shale, medium- and low-maturity shale oil, and oil-rich coal.

[0014] Furthermore, a temperature control tube is lowered into the horizontal well casing, a high-temperature packer is set at the right end of the horizontal section, and multiple temperature sensors are arranged in the horizontal section of the temperature control tube to monitor the reaction temperature of different reaction areas of the formation.

[0015] Furthermore, a plurality of electric water injection valves are arranged in the horizontal section of the horizontal well to inject water into the chemical reaction area in a targeted manner.

[0016] Furthermore, the heating well used for in-situ heat extraction is a double-casing structure, and the annular space is used to inject normal temperature water.

[0017] Furthermore, in step 2, the chemical reaction area is divided into a residue area, an autogenous heat area, a cracking area, a preheating area and a parent rock area, and the temperature decreases successively. The temperature range of the residue area is 550-800°C; the temperature range of the autogenous heat area is 450-550°C, the temperature range of the cracking area is 300-450°C, the temperature range of the preheating area is 200-300°C and the temperature of the parent rock area is lower than 100°C. The temperature ranges of the chemical reaction zones of the in-situ cracking will fluctuate and overlap due to changes in the injection and production process.

[0018] Furthermore, in step 2, the oxygen volume concentration in the oxygen-containing gas is 16-20%, the injection conditions of room temperature water are that the autogenous heat reaction is triggered and the temperature of the reaction zone is higher than 400°C, and the injection mass of water is 2-7wt% of the target reservoir mass.

[0019] Furthermore, in step three, the water-soluble catalyst for in-situ hydrogen production is Ca(OH)2 or Ca(OH)2+Na2CO3.

[0020] Furthermore, the in-situ heat generation stage may use one or several production wells according to actual needs.

[0021] Furthermore, the CO2 geological storage is injected into a reservoir rich in pores after mining in an ultra-close state, and the storage form is one or more of supercritical adsorption, mineralization precipitation and dissolution.

[0022] Through the above design scheme, the beneficial effects produced by the present invention are as follows:

[0023] 1. The present invention utilizes high-temperature injection of room-temperature water to enhance the in-situ cracking of unconventional energy sources by self-heating, thereby increasing the recovery rate of cracked oil and providing a hydrogen source, thereby improving the content of light components and saturated hydrocarbons in the cracked oil. The present invention utilizes high-temperature waste heat in the formation to react residual carbon with water to produce hydrogen in-situ, or utilizes heat released by oxidation of residual carbon with oxygen to produce heat in-situ. The present invention utilizes CO2 circulation to realize the recovery and in-situ storage of residual heat in the formation, thereby forming a comprehensive mining model for in-situ mining of unconventional energy sources with low input, high output, greenness, and low carbon.

[0024] 2. The multi-point temperature monitoring and controllable water injection device in the horizontal well of the present invention realizes real-time monitoring of the temperature of different areas and targeted water injection during autothermal in-situ cracking, which is conducive to real-time regulation of parameters during process implementation to maximize the energy return rate.

[0025] 3. The present invention adopts a normal temperature water-assisted autogenous heat in-situ cracking and mining mode. Oxygen provides heat for the organic matter cracking reaction, and a small amount of normal temperature water is injected to enhance pyrolysis. The water is not required to be in a supercritical state. The main function is displacement, and the reaction is auxiliary. Under the premise of not affecting the formation temperature, the physical and chemical properties of water change at high temperature, which has the functions of displacing oil and gas products, reducing the viscosity of heavy components, competitive adsorption and hydrogen supply, thereby reducing secondary coking reactions, realizing efficient recovery of cracked oil, and avoiding losses along the way when high-temperature water vapor is injected on the ground.

[0026] 4. The present invention utilizes the high-temperature waste heat of the target reservoir after autogenous thermal cracking, the reaction of water and residual carbon to produce hydrogen in situ or the exothermic reaction of residual carbon and oxygen, thereby realizing the utilization of high-temperature waste heat and improving the efficiency of organic matter conversion; at the same time, the circulation of CO2 in the target reservoir is utilized to recover the formation heat, and the abundant pore enrichment space after organic matter cracking and hydrogen production is used to seal CO2 in situ, thereby realizing the clean exploitation of unconventional energy. BRIEF DESCRIPTION OF THE DRAWINGS

[0027] Figure 1 This is a comprehensive schematic diagram of the unconventional energy in-situ oil and gas production and upgrading - hydrogen production - carbon storage of the present invention.

[0028] Figure 2 This is a cross-sectional schematic diagram of the in-situ oil and gas production and upgrading stage of the present invention.

[0029] Figure 3 It is a cross-sectional schematic diagram of the in-situ hydrogen production stage of the present invention.

[0030] Figure 4 This is a schematic diagram of the well layout for in-situ oil and gas production, upgrading, heat generation and carbon storage according to the present invention.

[0031] Figure 5 This is a comprehensive schematic diagram of the unconventional energy in-situ oil and gas production and upgrading, heat generation and carbon storage of the present invention.

[0032] 1-target reservoir; 2-top plate; 3-bottom plate; 4-heating well; 401-annular space; 5-horizontal well; 501-temperature control tube; 502-electric water injection valve; 503-temperature sensor; 6-production well; 7-fracturing seepage channel; 8-downhole heater; 9-air compressor; 10-boosting pump; 11-heat exchanger; 12-gas-liquid separation device; 13-gas storage tank; 14-oil-water separation device; 15-oil storage tank; 16-water storage tank; 17-temperature and pressure monitoring system; 18-power generation device; 19-residue zone; 20-autogenous heating zone; 21-cracking zone; 22-preheating zone; 23-original rock zone; 24-hydrogen production reaction advancement direction; 25-high-temperature oxidation zone; 26-in-situ hydrogen production zone; 27-water-soluble catalyst. DETAILED DESCRIPTION

[0033] The following will clearly and completely describe the technical solutions in the embodiments of the present invention in conjunction with the accompanying drawings. 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.

[0034] Example 1

[0035] A method for the integrated extraction of unconventional energy resources through in-situ oil and gas production and upgrading, hydrogen production, and carbon storage achieves efficient oil and gas recovery and full utilization of heat through four stages: in-situ oil and gas production and upgrading, in-situ hydrogen production from high-temperature waste heat in the formation, waste heat recovery, and geological carbon storage. The specific steps of this method are as follows:

[0036] Step 1: Figure 1 As shown, at least one heating well 4, one horizontal well 5, and one production well 6 are drilled within the production area. Specifically, the vertical section of the horizontal well is located adjacent to the heating well. The vertical wells are cemented with high-temperature cement slurry, and the horizontal sections are cemented after casing is run. The target reservoir 1 is staged and fractured using a fracturing fluid carrying proppant, forming interconnected fracture seepage channels 7 between the wells.

[0037] Multiple individually controllable electric water injection valves 502 are installed on the horizontal section casing of horizontal well 5. Four equally spaced electric water sprayers are positioned upwards along the casing ring. One electric water injection valve 502 is placed every 0.5m along the horizontal well's direction, enabling targeted water injection within the target area. A temperature control tube 501 is lowered into horizontal well 5. Multiple temperature sensors 503 are located within this tube to monitor the temperature of different reaction zones in the formation during production in real time. A high-temperature packer is also installed at the right end of the horizontal section.

[0038] Step 2: Insert a downhole heater 8 into the heating well 4. After the room temperature oxygen-containing gas is heated by the downhole heater 8, convection heating is applied to the target reservoir 1, causing the kerogen to crack and produce oil and gas products that are then mined to the surface. Specifically, when the reservoir temperature reaches above 300°C, the downhole heater 8 is turned off, and the room temperature oxygen reacts with some hydrocarbon products to produce exothermic oxidation, providing heat for subsequent organic matter cracking and triggering a self-heating chain reaction. Figure 2 As shown, between the heating well 4 and the production well 6, a residue zone 19 is formed in sequence, with a temperature range of 550-700°C; an autogenous heating zone 20 is formed, with a temperature range of 450-550°C; a cracking zone 21 is formed, with a temperature range of 300-450°C; a preheating zone 22 is formed, with a temperature range of 200-300°C; and a protolith zone 23 is formed, with a temperature below 100°C. The reaction zone gradually advances from the heating well 4 toward the production well 6.

[0039] Temperature sensors 503 within temperature control tube 501 monitor the temperature at different locations in the target reservoir 1 in real time. When the temperature of multiple sensors reaches 400°C, ambient-temperature water is injected into the annulus of horizontal well 5 in stages. Electric water injection valve 502, located in the area above 400°C, is opened, allowing water to enter the autogenous heating zone 20 and cracking zone 21, displacing the oil and gas products. This reduces the coking reaction of heavy components and increases the content of alkane components, achieving in-situ oil and gas production and quality improvement. After being pumped to the surface through production well 6, the oil and gas products undergo heat exchange with ambient-temperature gas in heat exchanger 11. They are then separated in gas-liquid separator 12 and oil-water separator 14. The initially heated oxygen-containing gas, cracked gas, and water are then reinjected into the target reservoir. This process is repeated until the oil and gas products are completely recovered.

[0040] Furthermore, in step 2, the oxygen-containing gas preferably has an oxygen volume concentration of 16-20%, the injection conditions of room temperature water are that the autogenous heat reaction is triggered and the reaction zone temperature is higher than 400°C, and the total mass of water is 2-7wt% of the target reservoir mass.

[0041] Step 3: Figure 3 As shown, oxygen-containing gas is continuously injected into the heating well 4, and a violent oxidation reaction occurs between the remaining organic matter and oxygen. A high-temperature oxidation zone 25 is formed between the heating well 4 and the horizontal well 5, providing the required heat for the subsequent reaction in the in-situ hydrogen production zone 26. At the same time, an aqueous solution with an ion concentration of 10% Ca(OH)2 or 10% Ca(OH)2+4% Na2CO3 is prepared in the water storage tank 16 and injected into the target formation through the annular space of the horizontal well 5. Under high-temperature catalysis, water reacts with the remaining carbon residue to generate CO2 and H2. Under the action of the water environment, part of the CO2 reacts chemically with alkaline minerals such as CaO / MgO in the formation to form precipitation, dissolve or adsorb in the rich pore structure of the formation. The remaining CO2, H2 and water are produced through the production well 6. After separation on the ground, H2 is stored in the gas storage tank, and water and CO2 are re-injected into the formation.

[0042] Furthermore, in step three, the injection parameters of oxygen and water are adjusted in real time according to the temperature monitoring of the formation, and are injected alternately. Specifically, when the temperature in the reaction area is lower than 550°C, the water injection is stopped and only oxygen is introduced. After the temperature in the reaction area rises, the oxygen injection is stopped and the water-based catalytic solution is continued to be injected to promote the reaction between water and residual carbon to generate H2.

[0043] Step 4: Recover temperature control tube 501, close horizontal well 5, remove downhole heater 8, and pressurize the cracked and industrially captured CO2 before reinjecting it through heater well 4 into target reservoir 1. Supercritical CO2 circulates within the reservoir, recovering waste heat from the formation. When the target reservoir temperature drops to 100°C, production well 6 is closed, and surface boosting equipment is used to pressurize the CO2, injecting it into the target reservoir in a supercritical state for in-situ storage.

[0044] Example 2

[0045] A method for the integrated in-situ oil and gas production and upgrading, heat generation, and carbon storage of unconventional energy is proposed. This method achieves efficient oil and gas recovery, efficient heat utilization, and in-situ CO2 storage through four stages: in-situ oil and gas production and upgrading, post-production residual carbon oxidation to generate heat, waste heat recovery, and geological carbon storage. The specific steps of this method are as follows:

[0046] Step 1: Figure 4 As shown, a seven-spot well pattern is employed within the production area. A heating well 4 is drilled in the center, and six production wells 6 are drilled in a regular hexagonal pattern around it. Casing is then run through the entire wellbore for cementing. The heating well 4 utilizes a double-casing structure, with temperature sensors positioned outside the casing to monitor the reservoir's reaction temperature. The target reservoir 1 is then staged with fracturing fluid, creating interconnected fracture seepage channels between the wells.

[0047] Step 2: Figure 5 As shown, a downhole heater 8 is lowered into the heating well 4. After being heated by the downhole heater 8, the ambient temperature oxygen-containing gas convectively heats the target reservoir 1, cracking the kerogen to produce oil and gas products. Specifically, when the reservoir temperature reaches above 300°C, the downhole heater 8 is turned off, and the ambient temperature oxygen-containing gas undergoes an exothermic oxidation reaction with some hydrocarbon products, providing heat for subsequent organic matter cracking. When the bottomhole sensor temperature exceeds 400°C, ambient temperature water is injected into the annular space 401 of the heating well 4 in stages. At high temperatures, the water instantly forms steam, displacing the migration of oil and gas products, reducing the coking reaction of heavy oil and increasing the content of light components, thereby achieving the purpose of in-situ oil and gas production and upgrading. After the oil and gas products are extracted and separated on the surface, the cracked gas is reinjected into the target reservoir, and the above operation is repeated until the oil and gas products are completely extracted from the production well.

[0048] Step 3, post-mining carbon residue oxidation heat generation stage, the mining well 6 is converted from oil production to heat production, the downhole heater 8 in the heating well 6 is removed, and oxygen is continued to be injected. The remaining carbon residue in the mining area fully reacts with the oxygen to generate a large amount of heat and CO2 gas in situ, and the high-temperature gas is heat exchanged and separated on the ground until the oxidation exothermic reaction ends.

[0049] Step 4: The separated, room-temperature CO2 is pressurized and circulated in a supercritical form for heat recovery, fully recovering the formation's heat. This recovered heat can be used for equipment operation and industrial power generation within the mining area. Simultaneously, in the presence of water, some of the CO2 is mineralized or adsorbed in the in-situ reservoir.

[0050] Step 4: When the temperature of the target reservoir 1 drops to 100°C, the production well 6 is closed, and the CO2 generated by cracking and industrially captured is injected into the target reservoir through the heating well 4 to achieve in-situ storage.

[0051] Furthermore, in this embodiment, one or several production wells 6 can be used according to actual needs.

[0052] Furthermore, the amount of electricity generated by burning the remaining carbon residue E1 is calculated as follows:

[0053]

[0054] Where E1 is the power generation, kW·h; Q is the calorific value of the residual carbon, kJ / kg; m is the total mass of the residual carbon, kg; and η is the total power generation efficiency.

[0055] Furthermore, after the carbon residue is burned, the formation is in a high-temperature environment, and the power generation capacity E2 of the recoverable heat in the reservoir is calculated as follows:

[0056]

[0057] Where E2 is the power generation, kW·h; Q is the calorific value of the residual carbon, kJ / kg; m is the total mass of the residual carbon, kg; c is the specific heat capacity, kJ / (kg·K); and η is the total power generation efficiency.

[0058] Furthermore, in this embodiment, the average temperature of the formation after oil and gas extraction is 400°C, the average calorific value of the remaining oil shale residue is 5000 kJ / kg, and the average density is 1.5 g / cm 3 The calorific value of combustion of oil shale residual carbon per unit volume is 5000MJ / m 3 Calculated based on a thermal efficiency of 70% and an electrical conversion efficiency of 35%, the power generation per unit volume of residual carbon is 510kW·h / m 3 When the temperature in the formation drops to 100°C, the specific heat capacity is 1.2 kJ / (kg·K), and the power generation per unit volume of heat is 37 kW·h / m 3 .

[0059] It will be apparent to those skilled in the art that the present invention is not limited to the details of the exemplary embodiments described above and that the invention can be embodied in other specific forms without departing from the spirit or essential characteristics of the invention. Therefore, the embodiments should be considered in all respects as illustrative and non-restrictive, and the scope of the invention is defined by the appended claims, not the foregoing description, and all variations within the meaning and range of equivalents of the claims are intended to be included therein. Any reference sign in a claim should not be construed as limiting the claim to which it relates.

[0060] In addition, it should be understood that although this specification is described in terms of implementation methods, not every implementation method contains only one independent technical solution. This narrative method of the specification is only for the sake of clarity. Those skilled in the art should regard the specification as a whole. The technical solutions in each embodiment can also be appropriately combined to form other implementation methods that can be understood by those skilled in the art.

Claims

1. A method for in-situ oil and gas production upgrading, waste heat utilization and carbon storage and joint production of unconventional energy, characterized by: The specific steps include: Step 1: Drill at least one heating well (4) and one production well (6) in the production area to the target reservoir (1). When the formation heat is used for in-situ hydrogen production, drill at least one horizontal well (5). The vertical section of the horizontal well is close to the heating well (4). After the casing is lowered, the entire well section is cemented to perform staged fracturing on the target reservoir, forming a fracturing seepage channel between the heating well and the production well. Step 2: inserting a downhole heater (8) into the heating well (4), and the oxygen-containing gas is heated to convectively heat the target reservoir (1). The oxygen and part of the oil and gas products react exothermically to trigger a self-heating chain reaction, and different chemical reaction areas are formed between the heating well (4) and the production well (6). An appropriate amount of room-temperature water is injected into the target reservoir (1) to displace the oil and gas migration, thereby increasing the oil and gas yield. After the oil and gas are extracted to the ground, they are heat-exchanged with the oxygen-containing gas at room temperature through the heat exchanger (11), and then enter the gas-liquid separation device (12) and the oil-water separation device (14) in sequence for separation. The cracked oil is stored in the oil storage tank (15), and the oxygen-containing gas, cracked gas, and water that have been heated initially are reinjected into the target reservoir. The above heating process is repeated until the oil and gas products are completely extracted. Step 3: Continue to inject room-temperature oxygen-containing gas into the heating well (4). When the formation heat is used for in-situ hydrogen production, the water-soluble catalytic solution is directionally injected into the formation through the horizontal well (5). Under high-temperature catalytic conditions, water reacts with the residual carbon and CO to generate CO2 and H2. After extraction to the ground and separation, the H2 is stored in the gas storage tank (13) and the CO2 is reinjected into the ground. The above operation is repeated until the reaction is completed. When the formation heat is used for in-situ heat extraction, water is no longer injected into the formation. Oxygen and the residual carbon are oxidized to release heat to generate a large amount of heat and CO2. The high-temperature CO2 is re-injected into the formation after heat exchange on the ground. Step 4: After the carbon residue has completed the reaction, supercritical CO2 is circulated in the target reservoir (1) to recover the heat from the high-temperature formation; Step 5: When the temperature of the target reservoir (1) drops to 100°C, the heating well (4) or the production well (6) is closed, and the CO2 generated by cracking and industrially captured is injected into the target reservoir (1) in a supercritical state to store the CO2 underground.

2. The unconventional energy in-situ oil and gas production and upgrading-waste heat utilization-carbon storage and joint production method according to claim 1 is characterized by: The unconventional energy sources are oil shale, medium and low-maturity shale oil and oil-rich coal.

3. The unconventional energy in-situ oil and gas production and upgrading-waste heat utilization-carbon storage and joint production method according to claim 1 is characterized by: A temperature control tube (501) is lowered into the horizontal well casing, a high-temperature packer is provided at the right end of the horizontal section, and a plurality of temperature sensors (503) are arranged in the horizontal section of the temperature control tube.

4. The unconventional energy in-situ oil and gas production and upgrading-waste heat utilization-carbon storage and joint production method according to claim 1 is characterized by: A plurality of electric water injection valves (502) are arranged in the horizontal section of the horizontal well (5).

5. The unconventional energy in-situ oil and gas production and upgrading-waste heat utilization-carbon storage and joint production method according to claim 1 is characterized by: The heating well (4) used for in-situ heat extraction is a double-layer casing structure, and the annular space (401) is used to inject normal temperature water.

6. The unconventional energy in-situ oil and gas production and upgrading-waste heat utilization-carbon storage and joint production method according to claim 1 is characterized by: In step 2, the chemical reaction area is divided into a residue area (19), an autogenous heat area (20), a cracking area (21), a preheating area (22) and a protolith area (23), and the temperature decreases successively. The temperature range of the residue area is 550-800°C; the temperature range of the autogenous heat area is 450-550°C, the temperature range of the cracking area is 300-450°C, the temperature range of the preheating area is 200-300°C and the temperature of the protolith area is lower than 100°C.

7. The unconventional energy in-situ oil and gas production and upgrading-waste heat utilization-carbon storage and joint production method according to claim 1 is characterized by: In step 2, the oxygen volume concentration in the oxygen-containing gas is 16-20%, the injection conditions of room temperature water are that the autothermal reaction is triggered and the temperature of the reaction zone is higher than 400°C, and the injection mass of water is 2-7wt% of the target reservoir mass.

8. The unconventional energy in-situ oil and gas production and upgrading-waste heat utilization-carbon storage and joint production method according to claim 1 is characterized by: In step 3, the water-soluble catalyst for in-situ hydrogen production is Ca(OH)2 or Ca(OH)2+Na2CO3.

9. The unconventional energy in-situ oil and gas production and upgrading-waste heat utilization-carbon storage and joint production method according to claim 1 is characterized by: The in-situ heat generation stage may utilize one or several production wells (6) according to actual needs.

10. The unconventional energy in-situ oil and gas production and upgrading-waste heat utilization-carbon storage and joint production method according to claim 1 is characterized by: The CO2 geological storage is injected into the reservoir with a large number of pores after mining in an ultra-close state, and the storage form is one or more of supercritical adsorption, mineralization precipitation and dissolution.

Images