Geothermal source assisted carbon capture and mineralization device and carbon capture and mineralization method thereof

Abstract

The invention relates to the technical field of carbon capture and mineralization, and provides a geothermal source assisted carbon capture and mineralization device and a carbon capture and mineralization method thereof. The geothermal source assisted carbon capture and mineralization device comprises a geothermal power generation unit, a heat storage unit, a carbon capture unit and a mineralization unit. High-temperature steam in geothermal fluid is used for power generation, and power is supplied to energy consumption devices in the heat storage unit and the carbon capture unit; the geothermal fluid waste heat is used for heat storage, a stable heat source is provided for the desorption process of the carbon capture unit in combination with electric heating of the heat storage device, carbon capture energy consumption is remarkably reduced, low-energy-consumption injection and mineralization of carbon dioxide are achieved, high energy efficiency, low operation cost and long-term stable storage capacity are achieved, and carbon emission reduction is achieved.

Description

Technical Field

[0001] This application relates to the field of carbon capture and mineralization technology, and in particular to geothermal source-assisted carbon capture and mineralization devices and methods thereof. Background Technology

[0002] Air-source carbon capture and mineralization (DAC-mineralization), as a key technology for achieving net removal of atmospheric carbon dioxide and building a zero-carbon energy system, has made significant progress in recent years through improvements in adsorbent performance, thermal integration optimization, and in-situ mineralization verification. The desorption of carbon dioxide typically requires a stable heat source of 80℃~120℃ and a certain degree of vacuum, consuming considerable energy. This not only increases energy consumption during recovery but also increases carbon emissions, potentially offsetting the carbon reduction benefits of carbon capture. While geothermal systems are a good heat source, their heat quality is dispersed and fluctuates greatly, making it difficult to achieve efficient matching with adsorbent regeneration conditions. Summary of the Invention

[0003] Therefore, it is necessary to provide a geothermal source-assisted carbon capture and mineralization device and its carbon capture and mineralization method to achieve stable energy and heat supply from geothermal sources and ensure stable carbon capture and mineralization.

[0004] In a first aspect, this application provides a geothermal source-assisted carbon capture and mineralization device, comprising:

[0005] The geothermal power generation unit includes a collector, a gas-liquid separator, a first steam turbine, and a generator. The collector is used to collect geothermal fluid; the feed end of the gas-liquid separator is connected to the collector, and the exhaust end is connected to the first steam turbine, which is used to separate the geothermal fluid into gas and liquid to form first steam, and uses the first steam to drive the first steam turbine; the first steam turbine is also connected to the generator to drive the generator to generate electricity.

[0006] The thermal storage unit includes a first heat exchanger and a thermal storage unit. The first heat exchanger is connected to the drain end of a gas-liquid separator and the thermal storage unit respectively, so as to use part of the liquid discharged from the gas-liquid separator to heat the first working fluid entering the thermal storage unit. The thermal storage unit is also connected to a generator, which supplies power to the thermal storage unit to heat the first working fluid inside the thermal storage unit.

[0007] The carbon capture unit includes a fan, a second heat exchanger, and at least one adsorber. The fan is electrically connected to a generator, and the exhaust end of the fan is connected to the air inlet end of each adsorber. The adsorbers are used to adsorb carbon dioxide from the air. The second heat exchanger is connected to a heat storage tank and each adsorber to heat the material in the adsorber using a first working fluid in the heat storage tank, which is used to desorb and release carbon dioxide from the adsorber. The first working fluid circulates between the second heat exchanger and the heat storage tank.

[0008] The mineralization unit, connected to the carbon capture unit, is used to inject the carbon dioxide discharged from the adsorber into the ground for mineralization.

[0009] In some embodiments, the thermal storage unit further includes a heat pump, a preheater, and a water storage tank. The preheater is connected to both the heat pump and the thermal storage tank. The heat pump provides a heat source for the preheater, and the preheater heats the first working fluid discharged from the second heat exchanger.

[0010] The heat pump is also connected to a first heat exchanger and a water storage tank, respectively. The heat pump is used to provide a heat source for the preheater using the liquid discharged from the first heat exchanger and to discharge the liquid after heat exchange into the water storage tank; and / or, the heat pump is also connected to a first steam turbine and a water storage tank, respectively. The heat pump is used to provide a heat source for the preheater using the liquid discharged from the first steam turbine and to discharge the liquid after heat exchange into the water storage tank.

[0011] In some embodiments, the geothermal power generation unit further includes a flash evaporator and a second steam turbine connected to the flash evaporator. The flash evaporator is connected to the discharge end of a gas-liquid separator and is used to flash-separate a portion of the liquid discharged from the gas-liquid separator to form second steam, which is then used to drive the second steam turbine. The second steam turbine is also connected to a generator to drive the generator to generate electricity.

[0012] In some implementations, the heat pump is also connected to a second steam turbine to use the liquid discharged from the second steam turbine as a heat source for the preheater and to discharge the heat-exchanged liquid to a water storage tank.

[0013] In some implementations, the geothermal power generation unit also includes a third steam turbine and a third heat exchanger.

[0014] The third heat exchanger is connected to the drain end of the third steam turbine and the flash evaporator respectively, so as to use the liquid discharged from the flash evaporator to heat the second working fluid in the third heat exchanger to form the third steam, and drive the third steam turbine through the third steam. The second working fluid circulates between the third heat exchanger and the third steam turbine. The third steam turbine is also connected to the generator to drive the generator to generate electricity.

[0015] In some embodiments, the carbon capture unit further includes a preprocessor disposed at the air inlet of the fan to filter the gas entering the fan; the preprocessor is also electrically connected to a generator that supplies power to the preprocessor.

[0016] And / or, the carbon capture unit also includes a vacuum pump connected to the adsorber, which provides negative pressure to the adsorber; the vacuum pump is also connected to a generator, which powers the vacuum pump.

[0017] And / or, the carbon capture unit also includes a condenser and a buffer tank, with the adsorber connected to the condenser, which is used to condense and remove moisture from the carbon dioxide discharged from the adsorber; the condenser is connected to the buffer tank for collecting and storing carbon dioxide.

[0018] And / or, the carbon capture unit includes at least four adsorbers connected in parallel.

[0019] In some implementations, the mineralization unit includes a mixer, a carbon dioxide dissolver, and an injector.

[0020] The mixer is connected to the buffer tank and the water storage tank to mix the carbon dioxide in the buffer tank with the liquid in the water storage tank; the carbon dioxide dissolver is connected to the mixer to increase the solubility of carbon dioxide in the carbon dioxide mixture discharged from the mixer; the injector is connected to the carbon dioxide dissolver to inject the carbon dioxide mixture into different underground locations for mineralization.

[0021] In some embodiments, the mineralization unit further includes a monitoring component, which includes a subsurface environmental parameter monitor and a seismic monitor located at the injection site of the injector. The subsurface environmental parameter monitor and the seismic monitor are also connected to the injector and are used to feed back environmental parameters at the subsurface injection site and the occurrence of earthquakes to the injector so as to adjust the injection volume of the injector.

[0022] Secondly, this application provides a method for carbon capture and mineralization using the geothermal source-assisted carbon capture and mineralization device of the first aspect, the method comprising:

[0023] The geothermal fluid collected by the collector is fed into a gas-liquid separator for separation. The first steam generated by the gas-liquid separator drives the first steam turbine to rotate, thereby driving the generator to generate electricity. The liquid generated by the gas-liquid separator is used to heat the first working fluid in the heat storage tank through the first heat exchanger, and the generator is used to supply electricity to the heat storage tank for heating.

[0024] A generator is used to power a fan, which delivers air to the adsorber to adsorb carbon dioxide. Then, the adsorber is heated and desorbed using a first working fluid in a heat storage tank, thereby separating carbon dioxide. The carbon dioxide is then introduced into a mineralization unit to be injected underground for mineralization.

[0025] In some implementations, the method also satisfies at least one of the following conditions:

[0026] (1) The temperature of the geothermal fluid is 180℃~280℃;

[0027] (2) The adsorbent in the adsorber includes at least one of amine-modified solid adsorbent and amine-hybrid porous support;

[0028] (3) The desorption pressure of the adsorber is 1 kPa to 10 kPa.

[0029] Compared with traditional technologies, this application has at least the following beneficial effects:

[0030] This application utilizes high-temperature steam from geothermal fluids to generate electricity, supplying power to energy-consuming devices in the thermal storage unit and carbon capture unit; and utilizes waste heat from the geothermal fluids for thermal storage, combined with the electric heating of the thermal storage device to provide a stable heat source for the desorption process of the carbon capture unit, significantly reducing carbon capture energy consumption, thereby achieving low-energy injection and mineralization of carbon dioxide, possessing high energy efficiency, low operating costs and long-term stable storage capabilities, and realizing carbon emission reduction. Attached Figure Description

[0031] Figure 1 This is a process structure diagram of a geothermal source-assisted carbon capture and mineralization device provided in one embodiment of this application;

[0032] Figure 2 This is a schematic diagram of the structure of a geothermal source-assisted carbon capture and mineralization device provided in one embodiment of this application.

[0033] The components are as follows: 100-Geothermal power generation unit; 110-Collector; 120-Gas-liquid separator; 130-First steam turbine; 140-Generator; 150-Flash evaporator; 160-Second steam turbine; 170-Third steam turbine; 180-Third heat exchanger; 200-Heat storage unit; 210-First heat exchanger; 220-Heat storage unit; 230-Heat pump; 240-Preheater; 250-Water storage tank; 300-Carbon capture unit; 310-Fan; 320-Second heat exchanger; 330-Adsorber; 340-Preprocessor; 350-Vacuum pump; 360-Condenser; 370-Buffer tank; Mineralization unit-400; 410-Mixer; 420-Carbon dioxide dissolver; 430-Injector; 440-Monitoring components. Detailed Implementation

[0034] The present application will be further described in detail below with reference to the embodiments and examples. These embodiments and examples are only for illustrating the present application and are not intended to limit the scope of the present application. The purpose of providing these embodiments and examples is to make the disclosure of the present application more thorough and comprehensive. It should also be understood that the present application can be implemented in many different forms and is not limited to the embodiments and examples described herein. Those skilled in the art can make various modifications or alterations without departing from the spirit of the present application, and the equivalent forms obtained also fall within the protection scope of the present application. In addition, numerous specific details are set forth in the following description to provide a fuller understanding of the present application. It should be understood that the present application can be implemented without one or more of these details.

[0035] In this application, "optionally," "optionally," and "optional" mean that something is optional, that is, it means that it is selected from either "with" or "without." If there are multiple "optional" entries in a technical solution, unless otherwise specified, and there are no contradictions or mutual constraints, each "optional" entry shall be independent.

[0036] In this application, the terms "first aspect," "second aspect," etc., are used for descriptive purposes only and should not be construed as indicating or implying relative importance or quantity, nor should they be construed as implicitly indicating the importance or quantity of the indicated technical features. Moreover, "first aspect," "second aspect," etc., serve only as a non-exhaustive enumeration and should be understood not to constitute a closed limitation on quantity.

[0037] In traditional technology, a medium-temperature geothermal source (90℃~150℃) is used to adjust the temperature to the required carbon dioxide desorption temperature (80℃~120℃) before being directly used as an auxiliary for efficient carbon dioxide adsorption in an adsorber. However, due to the large temperature fluctuations of the geothermal source, it is difficult to continuously and stably provide a heat source for the adsorber. This results in different adsorption effects at different stages, affecting the adsorption efficiency and preventing the achievement of stable carbon capture and mineralization.

[0038] Based on this, the first aspect of this application provides a geothermal source-assisted carbon capture and mineralization device, such as... Figure 1 As shown, it includes a geothermal power generation unit 100, a thermal storage unit 200, a carbon capture unit 300, and a mineralization unit 400.

[0039] Among them, such as Figure 2 As shown, the geothermal power generation unit 100 includes a collector 110, a gas-liquid separator 120, a first steam turbine 130, and a generator 140. The collector 110 is used to collect geothermal fluid. The feed end of the gas-liquid separator 120 is connected to the collector 110, and the exhaust end is connected to the first steam turbine 130. It is used to separate the geothermal fluid into gas and liquid components to form first steam, which is then used to drive the first steam turbine 130. The first steam turbine 130 is also connected to the generator 140 to drive the generator 140 to generate electricity.

[0040] The thermal storage unit 200 includes a first heat exchanger 210 and a thermal storage unit 220. The first heat exchanger 210 is connected to both the drain end of the gas-liquid separator 120 and the thermal storage unit 220, so as to use a portion of the liquid discharged from the gas-liquid separator 120 to heat the first working fluid entering the thermal storage unit 220. The thermal storage unit 220 is also connected to a generator 140, which supplies power to the thermal storage unit 220 to heat the first working fluid inside the thermal storage unit 220.

[0041] The carbon capture unit 300 includes a fan 310, a second heat exchanger 320, and at least one adsorber 330. The fan 310 is electrically connected to a generator 140, and the exhaust end of the fan 310 is connected to the air inlet end of each adsorber 330, which is used to adsorb carbon dioxide from the air. The second heat exchanger 320 is connected to a heat storage tank 220 and each adsorber 330, respectively, to heat the material in the adsorber 330 using a first working fluid in the heat storage tank 220, thereby desorbing and releasing carbon dioxide from the adsorber 330. The first working fluid circulates between the second heat exchanger 320 and the heat storage tank 220.

[0042] The mineralization unit 400 is connected to the carbon capture unit 300 and is used to inject the carbon dioxide discharged from the adsorber 330 into the ground for mineralization.

[0043] This application utilizes high-temperature steam from geothermal fluids to generate electricity, supplying power to energy-consuming devices in the thermal storage unit 200 and carbon capture unit 300; and utilizes waste heat from the geothermal fluids for thermal storage, combined with the electric heating of the thermal storage unit 220 to provide a stable heat source for the desorption process of the carbon capture unit 300, significantly reducing carbon capture energy consumption, thereby achieving low-energy injection and mineralization of carbon dioxide, possessing high energy efficiency, low operating costs and long-term stable storage capabilities, and realizing carbon emission reduction.

[0044] In some embodiments, the thermal storage tank 220 can be a molten salt tank or a high-temperature thermal oil tank. The first working medium can be molten salt or thermal oil, and the material of the first working medium can be selected reasonably according to the thermal storage requirements. Optionally, the designed energy storage time of the thermal storage tank 220 can be 4h to 24h, and can be selected as 6h to 24h. It is understood that the thermal storage tank 220 in this application can provide a stable heat source for the adsorber 330, effectively avoiding temperature changes in the heat source caused by geothermal source temperature fluctuations or grid regulation fluctuations, and can effectively improve the operational stability and energy utilization efficiency of the device.

[0045] In some embodiments, such as Figure 2 As shown, the heat storage unit 200 also includes a heat pump 230, a preheater 240 and a water storage tank 250. The preheater 240 is connected to the heat pump 230 and the heat storage tank 220 respectively. The heat pump 230 is used to provide a heat source for the preheater 240, and the preheater 240 is used to heat the first working fluid discharged from the second heat exchanger 320.

[0046] The heat pump 230 is also connected to the first heat exchanger 210 and the water storage tank 250 respectively. The heat pump 230 is used to provide a heat source for the preheater 240 using the liquid discharged from the first heat exchanger 210 and to discharge the liquid after heat exchange into the water storage tank 250; and / or, the heat pump 230 is also connected to the first steam turbine 130 and the water storage tank 250. The heat pump 230 is used to provide a heat source for the preheater 240 using the liquid discharged from the first steam turbine 130 and to discharge the liquid after heat exchange into the water storage tank 250.

[0047] This application utilizes a heat pump 230 to recover the heat from the wastewater discharge of the first steam turbine 130 and the first heat exchanger 210, thereby heating the first working fluid in the heat storage tank 220 and further improving heat recovery. For example, the liquid temperature of the exhaust steam from the first steam turbine 130 after condensation is approximately 40°C to 60°C. The heat pump 230 can raise this temperature to 80°C to 100°C or 85°C to 95°C, thus effectively heating the first working fluid after heat exchange. Furthermore, this application collects the liquid from the first steam turbine 130 and the first heat exchanger 210 into a water storage tank 250, which can be used as a water source during the carbon dioxide injection process in the mineralization unit 400, further reducing water loss.

[0048] Understandably, the operating parameters of the heat pump 230 can be adjusted according to the energy consumption of the heat pump 230 and the required temperature of the working fluid, so as to meet the requirements of minimum energy consumption and maximum heat recovery and utilization.

[0049] In some embodiments, such as Figure 2 As shown, the geothermal power generation unit 100 also includes a flash evaporator 150 and a second steam turbine 160 connected to the flash evaporator 150. The flash evaporator 150 is connected to the discharge end of the gas-liquid separator 120 and is used to flash separate a portion of the liquid discharged from the gas-liquid separator 120 to form second steam, which is then used to drive the second steam turbine 160. The second steam turbine 160 is also connected to a generator 140 to drive the generator 140 to generate electricity. Optionally, the pressure of the flash evaporator 150 can be 0.2 MPa to 0.5 MPa.

[0050] This application uses flash evaporation to separate the liquid in the gas-liquid separator 120 into a second steam, thereby using the second steam to drive the second turbine 160 to generate electricity, realizing multi-stage power generation, further reducing dependence on external energy, and significantly reducing the unit energy consumption of the carbon capture and storage process.

[0051] In some embodiments, the heat pump 230 is also connected to the second steam turbine 160 to provide a heat source for the preheater 240 using the liquid discharged from the second steam turbine 160, and to discharge the heat-exchanged liquid into the water storage tank 250. For example, the exhaust steam discharged from the second steam turbine 160, after cooling, has a temperature of approximately 40°C to 60°C, which can be raised to 80°C to 100°C by the heat pump 230, thereby effectively heating the heat-exchanged first working fluid as a heat source. Furthermore, the cooled liquid can be stored in the water storage tank for use as a water source.

[0052] In some implementations, such as Figure 2As shown, the geothermal power generation unit 100 also includes a third steam turbine 170 and a third heat exchanger 180. The third heat exchanger 180 is connected to both the third steam turbine 170 and the drain end of the flash evaporator 150, using the liquid discharged from the flash evaporator 150 to heat the second working fluid in the third heat exchanger 180 to form third steam. This third steam then drives the third steam turbine 170, and the second working fluid circulates between the third heat exchanger 180 and the third steam turbine 170. The third steam turbine 170 is also connected to a generator 140 to drive the generator to generate electricity. The third steam turbine 170 can be an Organic Rankine Cycle (ORC) turbine.

[0053] This application utilizes the high-temperature water discharged from a portion of the flash evaporator 150 as a heat source to heat the second working fluid in the third heat exchanger 180, generating third steam to drive the third steam turbine 170, which in turn drives the generator 140 to generate electricity, further utilizing geothermal energy to generate electricity, further reducing dependence on external energy, and significantly reducing the unit energy consumption of the carbon capture and storage process.

[0054] Understandably, the second working fluid can be selected based on the temperature of the liquid discharged from flash evaporator 150, thereby ensuring that the liquid discharged from flash evaporator 150 can form a stable third steam after heating and avoiding thermal decomposition of the working fluid. For example, the second working fluid can be a low-boiling-point organic working fluid with good thermal stability, such as isopentane, R245fa, or butane. Furthermore, the ORC turbine should be matched with a volumetric or small turbine expander based on the second working fluid, selecting a model to achieve high isentropic efficiency and wide operating condition adaptability, and to control turbine start-up, shutdown, and load to adjust the required amount of liquid discharged from flash evaporator 150. It should be noted that the ORC turbine can be equipped with working fluid replenishment and separation equipment, and the turbine's power generation efficiency can be adjusted according to power generation and heat storage conditions.

[0055] In some implementations, for example Figure 2 As shown, the carbon capture unit 300 also includes a pre-processor 340, which is located at the air inlet of the fan 310 to filter the gas entering the fan 310. The pre-processor 340 is also electrically connected to a generator 140, which supplies power to the pre-processor 340. This application uses a generator 140 to power the pre-processor 340, further reducing the device's energy consumption; simultaneously, it filters the air, reducing the content of dust and other impurities in the air, thus preventing damage to the adsorbent and affecting adsorption efficiency.

[0056] like Figure 2As shown, the carbon capture unit 300 also includes a vacuum pump 350 connected to the adsorber 330, which provides negative pressure to the adsorber 330. The vacuum pump 350 is also connected to a generator 140, which powers the vacuum pump 350. This application uses the vacuum pump 350 to provide negative pressure to the adsorption tower, further improving the carbon dioxide desorption efficiency. Furthermore, this application uses the generator 140 to power the vacuum pump 350, further reducing carbon capture energy consumption and achieving carbon emission reduction.

[0057] like Figure 2 As shown, the carbon capture unit 300 also includes a condenser 360 and a buffer tank 370. The adsorber 330 is connected to the condenser 360, which is used to condense and remove moisture from the carbon dioxide discharged from the adsorber 330. The condenser 360 is also connected to the buffer tank 370 for collecting and storing carbon dioxide. This application uses the condenser 360 to condense and remove moisture from the carbon dioxide, further improving its purity. Furthermore, the buffer tank 370 stores the carbon dioxide to ensure a stable supply during injection.

[0058] Optionally, the condenser 360 is also connected to the water reservoir 250 for collecting the condensed water into the water reservoir 250.

[0059] In some embodiments, such as Figure 2 As shown, the carbon capture unit 300 includes at least four adsorbers 330 connected in parallel. The four adsorbers 330 operate alternately in sequence, ensuring continuous adsorption and desorption processes in the carbon capture unit 300 at any given time. For example, the four adsorbers 330 are sequentially in adsorption, regeneration, cooling / pressure return, and transition positions. The cycle steps for each adsorber 330 include: adsorption, interbed isobaric equilibrium, heating and vacuum desorption, and cooling and pressure return, thereby achieving continuous carbon dioxide extraction. It is understood that valves and pumps can be installed on the feed and discharge lines of the adsorbers 330 as needed.

[0060] Furthermore, the various adsorbers 330 in this application can be interconnected, enabling kinetic energy recovery through multi-stage isobaric gas exchange between the adsorbers 330, thereby further reducing the energy consumption of the vacuum pump 350. For example, an inter-bed pressure equalization device can be used to connect the adsorbers 330 in the regeneration state and the adsorbers 330 in the cooling state to achieve multi-stage isobaric exchange, thereby maximizing energy recovery.

[0061] Specifically, the carbon capture unit 300, comprising at least four adsorbers 330 arranged in parallel, ensures that at any given time, at least one adsorber 330 is in an adsorption state, at least one adsorber 330 is in a regeneration (heating and vacuum desorption) state, at least one adsorber 330 is in a cooling / pressure return state, and at least one adsorber 330 is in a transitional state between steps, thereby achieving continuous, stable, and intermittently overlapping operation of carbon dioxide. Taking a carbon capture unit comprising a first adsorber, a second adsorber, a third adsorber, and a fourth adsorber as an example, the working state rotation sequence of the first adsorber is: adsorption - isobaric equilibrium - regeneration - cooling / pressure return; the working state rotation sequence of the second adsorber is: cooling / pressure return - adsorption - isobaric equilibrium - regeneration; the working state rotation sequence of the third adsorber is: regeneration - cooling / pressure return - adsorption - isobaric equilibrium; and the working state rotation sequence of the fourth adsorber is: isobaric equilibrium - regeneration - cooling / pressure return - adsorption. This sequential rotation ensures that each adsorber enters different operating steps in an equal-cycle manner during operation, achieving continuous circulation. Furthermore, the overlapping of steps allows the system as a whole to exhibit stable production capacity characteristics of continuous adsorption and desorption on a macroscopic scale.

[0062] The multi-stage isobaric gas equilibration process is performed sequentially among the four adsorbers in a fixed order, achieving a gradual pressure release and energy recovery from a high-pressure bed to a low-pressure bed. Specifically, after the first adsorber completes its adsorption step, its internal pressure approaches atmospheric pressure (e.g., 90 kPa to 100 kPa), the second adsorber is in the final stage of regeneration (pressure approximately 20 kPa to 40 kPa), the third adsorber is in the initial stage of cooling (40 kPa to 60 kPa), and the fourth adsorber is in the pressure recovery stage (60 kPa to 80 kPa). Before the first adsorber enters vacuum regeneration, the first and fourth adsorbers are connected for isobaric equalization, causing the pressure inside the first adsorber to decrease (approximately 70 kPa) and the pressure inside the fourth adsorber to increase. Then, the connection between the first and fourth adsorbers is severed, and the first and third adsorbers are connected for isobaric equalization, again causing the pressure inside the first adsorber to decrease (approximately 50 kPa) and the pressure inside the third adsorber to increase. Finally, the connection between the first and third adsorbers is severed, and the first and second adsorbers are connected for isobaric equalization, causing the pressure inside the first adsorber to decrease again (approximately 30 kPa) and the pressure inside the second adsorber to increase. Through these three isobaric equalizations, the pressure inside the first adsorber is gradually reduced to near the regeneration pressure. Only deep evacuation using a vacuum unit is needed at this lower reference pressure, significantly reducing the workload of the vacuum pump. Simultaneously, the second, third, and fourth adsorbers receive supplementary gas at different pressure levels, allowing them to partially replace external mechanical gas supply during cooling and pressure return stages, achieving internal energy circulation. This means that the pressure potential energy between each adsorber is maximized and recovered, significantly reducing the overall energy consumption of the system and ensuring continuous and efficient stable operation of the adsorbers.

[0063] It is understandable that the devices in the carbon capture unit 300 can be regulated by setting a controller, such as by controlling the opening and closing of the valves on each adsorber 330 to adjust the working state of each adsorber 330.

[0064] In some embodiments, such as Figure 2 As shown, the mineralization unit 400 includes a mixer 410, a carbon dioxide dissolver 420, and an injector 430.

[0065] The mixer 410 is connected to the buffer tank 370 and the water storage tank 250 respectively to mix the carbon dioxide in the buffer tank 370 with the liquid in the water storage tank 250; the carbon dioxide dissolver 420 is connected to the mixer 410 to improve the solubility of carbon dioxide in the carbon dioxide mixture discharged from the mixer 410; and the injector 430 is connected to the carbon dioxide dissolver 420 to inject the carbon dioxide mixture into different underground locations for mineralization.

[0066] Optionally, at least two-stage compressors can be used to introduce carbon dioxide from the buffer tank 370 into the mixer 410. The pressure of the compressed carbon dioxide is 15MPa to 25MPa, optionally 20MPa to 25MPa, to meet the requirements for carbon dioxide dissolution and the high pressure required for underground injection. Furthermore, the compressors are also powered by a generator 140 to further reduce energy consumption.

[0067] Optionally, the carbon dioxide dissolver 420 can be a multi-stage spray dissolver or a packed bed dissolver, thereby increasing the solubility of carbon dioxide in water, reducing the pH of the carbon dioxide mixture, increasing the driving force for rock leaching, and ensuring mineralization efficiency. The pH of the carbon dioxide mixture discharged from the carbon dioxide dissolver 420 can be 3-6.

[0068] In some embodiments, a high-pressure injection pump can be used to deliver the carbon dioxide mixture to the injector 430. It is understood that the injection pressure of the carbon dioxide mixture can be controlled to be lower than the formation fracturing pressure, optionally 10% to 20% lower, to avoid geological hazards. For example, the injection pressure can be 18 MPa to 25 MPa, optionally 20 MPa to 25 MPa.

[0069] Understandably, the injection location and method can be selected based on the geological conditions. For example, the injector 430 can be a directional perforated injection well or a multi-point distribution injection well, or multiple wells can be arranged in parallel to expand the reaction contact area between the carbon dioxide mixture and the minerals and to distribute the injection pressure. The injection depth of the carbon dioxide mixture can be 1500m~2600m, preferably 2000m~2500m, to maintain the dissolved state of carbon dioxide under high temperature and high pressure conditions, promoting in-situ mineralization. For example, the injection location can be a fractured basalt or andesite belt, where the geothermal temperature at the injection depth is approximately 120℃~200℃. Furthermore, when there is an aquifer above the injection location, an aquitard can be set between the injection location and the aquifer, or the selected injection location can have a complete natural cap layer with good geological sealing to prevent the injected carbon dioxide solution from migrating to the surface and causing pollution of the aquifer or surface water.

[0070] Understandably, all pipelines and equipment in mineralization unit 400 should be made of acid-resistant and high-temperature-resistant alloys to improve corrosion resistance and extend equipment service life. For example, high-nickel alloys or structures with polymer or composite linings can be used.

[0071] In some embodiments, such as Figure 2As shown, the mineralization unit 400 also includes a monitoring component 440, which includes a subsurface environmental parameter monitor and a seismic monitor located at the injection position of the injector 430. The subsurface environmental parameter monitor and the seismic monitor are also connected to the injector 430 respectively, and are used to feed back the environmental parameters of the subsurface injection position and the occurrence of earthquakes to the injector 430 so as to adjust the injection volume of the injector 430.

[0072] The system includes underground environmental monitors that can be deployed at the injection site and surrounding areas to monitor changes in pressure, temperature, pH, conductivity, carbon dioxide concentration, and the concentration of various metal ions (such as calcium, magnesium, and iron ions) at the injection site and surrounding areas, either online or periodically. Combined with seismic monitors, these monitors can detect stress changes at the injection site and assess the risk of geological hazards. Furthermore, a tracer dosing device can be installed to inject the carbon dioxide mixture simultaneously, monitoring and tracking the fluid flow to identify leak locations and pinpoint mineralized areas. Additionally, a controller can adjust the injection volume and pressure of the injector 430 based on feedback signals from the underground environmental monitors and seismic monitors, automatically implementing decompression, injection cessation, and bypass or pressure relief measures to ensure mineralization safety.

[0073] It is understood that generator 140 can supply power to various electrical equipment in the geothermal auxiliary carbon capture and mineralization device, thereby effectively reducing energy consumption. In some embodiments, generator 140 is also connected to the power grid to cope with situations where generator 140 cannot meet functional requirements in case of emergencies. Optionally, a controller can be added to control the grid connection switching, grid connection synchronization, and grid connection protection (such as anti-islanding protection, over / under voltage and frequency protection) of generator 140. For example, an automatic bypass / isolation circuit can be set to ensure backup power or UPS for critical loads and in case of grid failure. Therefore, by optimizing the controller algorithm, self-consumption and energy storage charging and discharging can be dynamically optimized according to real-time load, heat demand, energy storage status, and electricity price signals, and priority can be given to ensuring the power supply to critical equipment and the safety of grid operation.

[0074] The second aspect of this application provides a method for carbon capture and mineralization using the geothermal source-assisted carbon capture and mineralization device of the first aspect, the method comprising:

[0075] The geothermal fluid collected by the collector 110 is passed into the gas-liquid separator 120 for separation. The first steam generated by the gas-liquid separator 120 drives the first steam turbine 130 to rotate, thereby driving the generator 140 to generate electricity. The liquid generated by the gas-liquid separator 120 is used to heat the first working fluid in the heat storage tank 220 through the first heat exchanger 210, and the generator 140 is used to supply electricity to heat the heat storage tank 220.

[0076] The generator 140 supplies power to the fan 310, which delivers air to the adsorber 330 to adsorb carbon dioxide. Then, the first working fluid in the heat storage tank 220 is used to heat and desorb the adsorber 330, thereby separating carbon dioxide. The carbon dioxide is then introduced into the mineralization unit 400 to be injected underground for mineralization.

[0077] In some embodiments, the temperature of the geothermal fluid is 180°C to 280°C, for example, it can be 180°C, 190°C, 200°C, 210°C, 220°C, 230°C, 240°C, 250°C, 260°C, 270°C or 280°C.

[0078] It is understood that this application may select a suitable adsorbent according to the adsorption requirements. In some embodiments, the adsorbent in the adsorber 330 includes at least one of an amine-modified solid adsorbent and an amine-hybridized porous support.

[0079] The desorption pressure of the adsorber 330 is 1 kPa to 10 kPa, and can be selected as 1 kPa to 5 kPa. This application selects the adsorbent and desorption pressure as described above to reduce the vacuum power consumption of adsorbent regeneration while balancing the desorption rate and carbon dioxide purity, enabling the carbon dioxide volume content to reach 95% to 99%. Furthermore, through synergistic optimization of inter-bed pressure equalization, waste heat recovery, and supplemental heating by the industrial heat pump 230, the energy consumption of carbon capture is significantly reduced.

[0080] In some embodiments, the liquid discharged from the gas-liquid separator 120 enters the flash evaporator 150 to form second steam, which drives the second turbine 160 to generate electricity using the generator 140. It should be noted that the liquid discharged from the flash evaporator 150 can partially enter the first heat exchanger 210 to exchange heat with the first working fluid in the heat storage tank 220 for heat storage. It can also partially enter the third heat exchanger 180 to heat the second working fluid and drive the third turbine 170 to generate electricity. Optionally, by volume, 25%~35% of the liquid discharged from the flash evaporator 150 enters the third heat exchanger 180, and 65%~75% enters the first heat exchanger 210. It is understood that the liquid distribution can be reasonably adjusted according to power generation and heat storage requirements. When power generation demand is high in the short term, the volume of liquid entering the third heat exchanger 180 can be increased to maximize short-term power generation; when a stable heat supply to the adsorber 330 is required, the volume of liquid entering the first heat exchanger 210 can be increased to achieve stable heat storage.

[0081] It is understood that each device in this application can be controlled by data acquisition, monitoring and controller. Furthermore, it can be combined with model predictive control (MPC) algorithm for collaborative optimization scheduling to achieve dynamic optimal matching between power generation, waste heat recovery, carbon capture and mineralization, so as to achieve closed loop of operating parameters, monitoring data and prediction model for online process adjustment and energy consumption minimization.

[0082] The embodiments of this application will be described in detail below with reference to examples. It should be understood that these embodiments are for illustrative purposes only and are not intended to limit the scope of this application. For experimental methods in the following embodiments where specific conditions are not specified, please refer to the guidelines given in this application, or follow experimental manuals or conventional conditions in the art, or follow the conditions recommended by the manufacturer, or refer to experimental methods known in the art.

[0083] Example 1

[0084] Taking the Yangbajing Geothermal Field in Tibet Autonomous Region as an example, its geothermal system consists of multiple reservoirs (shallow, deep first reservoir, and deep second reservoir), all belonging to the same hydraulic system. The shallow reservoir is buried at a depth of approximately 180m-280m, with a temperature of approximately 130℃-173℃, and the geothermal fluid is a mixed liquid / steam type fluid, predominantly liquid. The deep first reservoir is buried at a depth of approximately 950m-1350m, with a temperature of approximately 250℃-280℃. The deep second reservoir is buried at a depth of approximately 1850m, with a temperature of approximately 330℃. The water's chemical characteristics are Cl... - -Na + This type of reservoir contains a significant amount of carbon dioxide gas. Its reservoir lithology is dominated by basalt and rhyolite, rich in silicate minerals such as plagioclase, pyroxene, and olivine; the aquifer and hydrochemical composition contain Ca. 2+ Mg 2+ Fe 2+ Plasma, with a slightly alkaline to neutral pH, is conducive to in-situ mineralization reactions. Well-developed fissures and fault channels provide pathways for injection and reaction.

[0085] The deep production well is selected as the collector 110. The temperature of the geothermal fluid it produces is about 220℃~280℃, the wellhead pressure is about 8MPa~10MPa, and the steady-state flow rate of a single well is about 60L / s~80L / s.

[0086] The geothermal fluid first enters the gas-liquid separator 120, where the first steam and liquid phases are separated. The first steam is then fed into the first steam turbine 130, which is a high-pressure turbine designed to withstand pressures of approximately 5MPa to 8MPa. The generator set output power is approximately 3MW / well to 5MW / well.

[0087] The liquid phase enters the flash evaporator 150 and is depressurized to approximately 0.2 MPa to 0.5 MPa, forming a second steam to drive the second turbine 160. The second turbine 160 is a low-pressure turbine with a power generation capacity of approximately 1 MW to 2 MW. By volume, 30% of the liquid phase discharged from the flash evaporator 150 is allocated to the third heat exchanger 180 to drive the third turbine 170, which in turn drives the generator 140 to generate electricity. The third turbine 170 is an ORC turbine, using isopentane as the working fluid to accommodate a heat source of 100°C to 200°C, with a power generation capacity of approximately 0.5 MW to 2 MW. The remaining 70% of the liquid is fed into the first heat exchanger 210 to heat the heat transfer oil in the heat storage tank 220 to 100°C to 120°C for desorption in the adsorber 330. The heat storage capacity in the heat storage tank 220 should meet the requirements for approximately 12 hours of operation to cope with temperature fluctuations and low-load operation at night.

[0088] The exhaust steam generated by each steam turbine is cooled to a temperature of approximately 40°C to 60°C. The liquid discharged from the third heat exchanger 180 is also at a temperature of approximately 40°C to 60°C. This liquid is then transported to the heat pump 230 to raise the temperature to 80°C to 100°C, thereby preheating the cooled heat transfer oil in the heat storage tank 220. The cooled liquid then enters the water storage tank 250 for later use.

[0089] Air filtered by preprocessor 340 is blown into adsorber 330 by fan 310. The adsorbent in adsorber 330 is a solid amine-based hybrid material with a carbon dioxide capture rate of approximately 85%~90%. After adsorption, adsorber 330 undergoes desorption at a temperature of 100℃~120℃ and a vacuum pressure of approximately 1kPa~5kPa (absolute pressure). Adsorber 330 is heated by heat transfer oil in heat storage tank 220 via first heat exchanger 210. During desorption, a bed pressure equalization mechanism is used to recover gas pressure energy and reduce vacuum formation power consumption. After desorption, the gas is condensed and dehydrated before being stored in buffer tank 370, and the condensate is sent to water storage tank 250 for later use.

[0090] The carbon dioxide in the buffer tank 370 is first compressed to a pressure of 10MPa~15MPa in a primary stage, and then compressed to a pressure of 20MPa~25MPa in a secondary stage to meet the injection pressure requirements of the formation and be below the formation fracturing limit. The compressed gas is then passed into the mixer 410 to mix with condensate, and then into the carbon dioxide dissolver 420 to ensure that the carbon dioxide is highly soluble in water, forming a carbon dioxide mixture containing carbonic acid (H2CO3).

[0091] A carbon dioxide mixture is injected into a basalt fracture zone at a depth of approximately 2000m-2500m to induce mineralization. Approximately 30%-70% of the injected carbon dioxide is mineralized within about four months after injection; the overall mineralization efficiency (primarily calcite) reaches 70%-95%, with an estimated annual carbon dioxide storage capacity of 10 tons per well. 5 ton.

[0092] Example 2

[0093] Taking the Geji Geothermal Field in Ali Prefecture, Tibet Autonomous Region as an example, its geothermal system is characterized by deep, high-temperature hydrothermal fluids and fracture conduction. The reservoir temperature ranges from approximately 200℃ to 280℃, with some wellhead temperatures reaching approximately 300℃. The wellhead pressure is approximately 8MPa to 12MPa. The lithology of the formation is mainly basalt, andesite, and tuffaceous volcanic clastic rocks. The reservoir contains relatively abundant Ca. 2+ Mg 2+ Fe 2+ These layers readily release metal ions, and the fractures provide excellent contact pathways, making them a preferred target layer for in-situ carbon dioxide mineralization and storage. Due to the overall scarcity of groundwater, water recycling can be achieved through condensate recovery and recharge via local aquifer faults.

[0094] The deep production well is selected as the collector 110. The temperature of the geothermal fluid it produces is about 240℃~260℃, the wellhead pressure is about 8MPa~12MPa, and the steady-state flow rate of a single well is about 60L / s~120L / s.

[0095] The geothermal fluid first enters the gas-liquid separator 120, where the first steam and liquid phases are separated. The first steam then enters the first steam turbine 130, which is a high-pressure steam turbine designed to withstand pressures of approximately 5MPa to 9MPa, with a generator set output power of approximately 3MW / well to 6MW / well.

[0096] The liquid phase enters the flash evaporator 150 and is depressurized to approximately 0.2 MPa to 0.4 MPa, forming a second steam to drive the second turbine 160. The second turbine 160 is a low-pressure turbine with a power generation capacity of approximately 1 MW to 2 MW. By volume, 30% of the liquid phase discharged from the flash evaporator 150 is allocated to the third heat exchanger 180 to drive the third turbine 170, which in turn drives the generator 140 to generate electricity. The third turbine 170 is an ORC turbine, using isopentane as the working fluid to accommodate heat sources of 100°C to 200°C, with a power generation capacity of approximately 0.5 MW to 2 MW. The remaining 70% of the liquid is fed into the first heat exchanger 210 to heat the heat transfer oil in the heat storage tank 220 to 100°C to 120°C for use in the adsorber 330 for desorption. The heat storage capacity in the heat storage tank 220 should meet the operating requirements for approximately 12 hours to cope with temperature fluctuations and low-load operation at night.

[0097] The exhaust steam generated by each steam turbine is cooled to a temperature of approximately 40°C to 70°C. The liquid discharged from the third heat exchanger 180 is also at a temperature of approximately 40°C to 70°C. This liquid is then transported to the heat pump 230 to raise the temperature to 80°C to 100°C, thereby preheating the cooled heat transfer oil in the heat storage tank 220. The cooled liquid then enters the water storage tank 250 for later use.

[0098] Air filtered by preprocessor 340 is blown into adsorber 330 by fan 310. The adsorbent in adsorber 330 is a solid amine-based hybrid material with a carbon dioxide capture rate of approximately 85%~90%. After adsorption, adsorber 330 undergoes desorption at a temperature of 100℃~120℃ and a vacuum pressure of approximately 1kPa~5kPa (absolute pressure). Adsorber 330 is heated by heat transfer oil in heat storage tank 220 via first heat exchanger 210. During desorption, a bed pressure equalization mechanism is used to recover gas pressure energy and reduce vacuum formation power consumption. After desorption, the gas is condensed and dehydrated before being stored in buffer tank 370, and the condensate is sent to water storage tank 250 for later use.

[0099] The carbon dioxide in the buffer tank 370 is first compressed to a pressure of 10MPa~15MPa in a primary stage, and then compressed to a pressure of 20MPa~25MPa in a secondary stage to meet the injection pressure requirements of the formation and be below the formation fracturing limit. The compressed gas is then passed into the mixer 410 to mix with condensate, and then into the carbon dioxide dissolver 420 to ensure that the carbon dioxide is highly soluble in water, forming a carbon dioxide mixture containing carbonic acid (H2CO3).

[0100] Carbon dioxide mixtures were injected to depths of approximately 2200m-2600m for mineralization. Under the high temperature and pressure conditions of Geji, the release rate of soluble metals and the precipitation rate of carbonates in basalt were significantly accelerated, and the annual carbon dioxide sequestration of a single well could reach 10 5 More than one ton.

[0101] Therefore, as can be seen from the above embodiments, this application has at least the following beneficial effects, including:

[0102] (1) This application solves the problems of mismatched geothermal energy grades and dispersed heat energy that are difficult to effectively couple in traditional technologies by integrating a system of "geothermal power generation - preheating recovery - carbon capture - mineralization and storage". Specifically, this application adopts a multi-level cascade utilization of geothermal energy, coordinating geothermal fluid steam, flash waste heat, ORC condensation heat with the industrial heat pump 230 temperature-raising system to provide a stable and renewable heat source for the regeneration of the adsorber 330. This design not only achieves a fully renewable supply of heat absorption, but also significantly reduces the energy consumption per unit of carbon dioxide capture, avoiding the rebound effect of fossil energy. Therefore, this application, through high-temperature steam-driven power generation and medium- and low-temperature waste heat reuse, coordinates to ensure the continuous and stable operation of carbon capture and mineralization, realizes multi-level gradient utilization of energy, reduces the use of external energy, significantly reduces energy consumption in the carbon capture and storage process, greatly improves the utilization rate of geothermal energy and the energy quality matching degree of the system, and realizes the efficient coupling and utilization of energy and carbon flow. In addition, it can be used in conjunction with model predictive control (MPC) algorithms to achieve dynamic scheduling and balancing of energy demand on the generation, capture, and injection sides, thereby ensuring efficient operation and minimum energy consumption of the system under load fluctuations.

[0103] (2) In this application, four adsorbers 330 are connected in parallel and alternately in the carbon capture unit 300, and combined with multi-stage pressure equalization between beds, carbon dioxide is continuously produced and the operating power of vacuum pump 350 is reduced, thereby realizing energy recovery and flow field stability, significantly reducing the energy consumption of carbon capture unit 300 and improving capture efficiency.

[0104] (3) This application employs a mixer 410 and a carbon dioxide dissolver 420 to increase the solubility of carbon dioxide. It also utilizes directional perforation and multi-point distribution to expand the contact area between the carbon dioxide mixture and the minerals, achieving homogenization and dynamic renewal of the solution-rock reaction interface. This effectively improves the mineralization reaction rate and the stability of mineralization storage, solving problems such as slow mineralization reactions and pore passivation in basalt and andesite. Furthermore, the integrated underground environmental parameter monitoring network and seismic monitoring enable real-time tracking of pressure, temperature, and chemical changes in the injection area, and provide an automatic injection stop and risk response mechanism, significantly improving the safety and reliability of the storage.

[0105] In summary, this application achieves closed-loop coupling of geothermal power generation and carbon dioxide sequestration within the same energy flow system, outputting electricity while permanently sequestering carbon, thus realizing a dual cycle of matter and energy for energy production and carbon emission reduction. The power generation unit can not only integrate electricity into the grid to meet regional energy demand but also partially supply its own operating load, thereby achieving energy self-sufficiency. The carbon capture unit 300 and mineralization unit 400 enable long-term safe disposal of carbon dioxide, reducing environmental burden and lowering the unit cost of carbon capture and sequestration. This not only breaks through the technical bottlenecks of high energy consumption and low coupling in traditional carbon capture but also achieves deep synergy between energy production and carbon negative emissions, providing a new solution to the "carbon sink" problem in carbon cycle research.

[0106] The technical features of the above embodiments can be combined in any way. For the sake of brevity, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.

[0107] The embodiments described above are merely illustrative of several implementation methods of this application, and while the descriptions are specific and detailed, they should not be construed as limiting the scope of the application. It should be noted that those skilled in the art can make various modifications and improvements without departing from the concept of this application, and these modifications and improvements all fall within the scope of protection of this application. Therefore, the scope of protection of this application should be determined by the appended claims.

Claims

1. A geothermal source assisted carbon capture and mineralization apparatus, characterized in that, The geothermal power generation unit comprises a collector, a gas-liquid separator, a first steam turbine and a power generator. The collector is used for collecting geothermal fluid. The gas-liquid separator is connected with the collector at an inlet end and connected with the first steam turbine at an exhaust end, and is used for separating the geothermal fluid into a first steam and driving the first steam turbine by the first steam; the first steam turbine is further connected with the power generator, and is used for driving the power generator to generate power. The heat storage unit comprises a first heat exchanger and a heat storage device; the first heat exchanger is connected with the liquid outlet end of the gas-liquid separator and the heat storage device respectively, and is used for heating a first working medium entering the heat storage device by using part of the liquid discharged from the gas-liquid separator; the heat storage device is further connected with the power generator, and the power generator supplies power to the heat storage device to heat the first working medium in the heat storage device. The carbon capture unit comprises a fan, a second heat exchanger and at least one adsorber; the fan is electrically connected with the power generator, the exhaust end of the fan is connected with the gas inlet end of each adsorber respectively, and the adsorber is used for adsorbing carbon dioxide in the air; the second heat exchanger is connected with the heat storage device and each adsorber respectively, and is used for heating the material in the adsorber by using the first working medium in the heat storage device, so as to desorb and discharge carbon dioxide from the adsorber; the first working medium circulates between the second heat exchanger and the heat storage device. The mineralization unit is connected with the carbon capture unit, and is used for injecting the carbon dioxide discharged from the adsorber into the ground for mineralization. The heat storage unit further comprises a heat pump, a preheater and a water storage device; the preheater is connected with the heat pump and the heat storage device respectively; the heat pump is used for providing a heat source for the preheater; and the preheater is used for heating the first working medium discharged from the second heat exchanger.

2. The geothermal source assisted carbon capture and mineralization device of claim 1, wherein, The heat pump is further connected with the first heat exchanger and the water storage device respectively; the heat pump is used for providing a heat source for the preheater by using the liquid discharged from the first heat exchanger, and discharging the heat-exchanged liquid into the water storage device. The heat pump is further connected with the first steam turbine and the water storage device; the heat pump is used for providing a heat source for the preheater by using the liquid discharged from the first steam turbine, and discharging the heat-exchanged liquid into the water storage device. The geothermal power generation unit further comprises a flash evaporator and a second steam turbine connected with the flash evaporator.

3. The geothermal source assisted carbon capture and mineralization device of claim 2, wherein, The flash evaporator is connected with the liquid outlet end of the gas-liquid separator, and is used for flash evaporation and separation of part of the liquid discharged from the gas-liquid separator to form a second steam, and driving the second steam turbine by the second steam; the second steam turbine is further connected with the power generator, and is used for driving the power generator to generate power. The heat pump is further connected with the second steam turbine, so as to provide a heat source for the preheater by using the liquid discharged from the second steam turbine, and discharge the heat-exchanged liquid into the water storage device.

4. The geothermal source assisted carbon capture and mineralization device of claim 3, wherein, The geothermal power generation unit further comprises a third steam turbine and a third heat exchanger.

5. The geothermal source assisted carbon capture and mineralization device of claim 3, wherein, ​ The third heat exchanger is connected with the third steam turbine and the flash evaporator respectively to heat the second working medium in the third heat exchanger by using the liquid discharged from the flash evaporator to form the third steam, and drive the third steam turbine by the third steam, and the second working medium circulates between the third heat exchanger and the third steam turbine; the third steam turbine is also connected with the power generator to drive the power generator to generate electricity.

6. The geothermal source assisted carbon capture and mineralization device of any one of claims 2-5, wherein, The carbon capture unit further comprises a pre-treater arranged at the air inlet end of the fan to filter the gas entering the fan; the pre-treater is also electrically connected with the power generator, and the power generator supplies power to the pre-treater; And / or, the carbon capture unit further comprises a vacuum pump connected with the adsorber respectively, and the vacuum pump is used to provide negative pressure for the adsorber; the vacuum pump is also connected with the power generator, and the power generator is used to supply power to the vacuum pump; And / or, the carbon capture unit further comprises a condenser and a buffer tank, the adsorber is connected with the condenser, and the condenser is used to condense and remove water from the carbon dioxide discharged from the adsorber; the condenser is connected with the buffer tank to collect and store carbon dioxide; And / or, the carbon capture unit comprises at least four adsorbers connected in parallel.

7. The geothermal source assisted carbon capture and mineralization device of claim 6, wherein, The mineralization unit comprises a mixer, a carbon dioxide dissolver and an injector; The mixer is connected with the buffer tank and the water storage device respectively to mix the carbon dioxide in the buffer tank with the liquid in the water storage device; the carbon dioxide dissolver is connected with the mixer to improve the solubility of carbon dioxide in the mixed liquid discharged from the mixer; the injector is connected with the carbon dioxide dissolver to inject the carbon dioxide mixed liquid into different positions of the underground for mineralization.

8. The geothermal source assisted carbon capture and mineralization device of claim 7, wherein, The mineralization unit further comprises a monitoring assembly, which comprises an underground environment parameter monitor and a seismic monitor arranged at the injection position of the injector, and the underground environment parameter monitor and the seismic monitor are also connected with the injector respectively to feed back the environment parameters of the underground injection position and the occurrence of the earthquake to the injector to adjust the injection amount of the injector.

9. A method of carbon capture and mineralization using the geothermal source assisted carbon capture and mineralization device of any one of claims 1-8, characterized in that, The method comprises: The geothermal fluid collected by the collector is separated in the gas-liquid separator, the first steam formed by the gas-liquid separator is used to drive the first steam turbine to rotate, thereby driving the power generator to generate electricity; the liquid formed by the gas-liquid separator is used to heat the first working medium in the heat storage device through the first heat exchanger, and the heat storage device is powered and heated by the power generator; The fan is powered by the power generator to transport air to the adsorber to adsorb carbon dioxide; then the first working medium in the heat storage device is used to heat and desorb the adsorber, thereby separating and obtaining carbon dioxide; the carbon dioxide is introduced into the mineralization unit to be injected into the underground for mineralization.

10. The method of claim 9, wherein, The method further satisfies at least one of the following conditions: (1) the temperature of the geothermal fluid is 180℃-280℃; (2) the adsorbent in the adsorber comprises at least one of an amine group modified solid adsorbent and an amine hybrid porous carrier; (3) the desorption pressure of the adsorber is 1 kPa to 10 kPa.

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