A method and system for carbon dioxide sequestration

Abstract

This invention discloses a carbon dioxide sequestration method and sequestration system. The sequestration method includes the following steps: (1) injecting an aqueous solution of 1,3-dioxolane into a target geological area; (2) injecting the gas to be sequestrated into the target geological area, generating carbon dioxide hydrate through a reaction. The sequestration system includes a monitoring unit, a delivery unit, and a hydration reaction unit; the delivery unit and the hydration reaction unit are connected; the delivery unit includes a horizontal injection well and a horizontal gas injection well; the monitoring unit includes a horizontal monitoring well. The carbon dioxide sequestration method and sequestration system provided by this invention utilize the thermodynamic and kinetic dual promoter 1,3-dioxolane to achieve carbon dioxide sequestration in large-scale scenarios, realizing efficient, rapid, and environmentally friendly CO2 geological sequestration.

Description

Technical Field

[0001] This invention relates to the field of carbon dioxide sequestration technology, and more particularly to a carbon dioxide sequestration method and sequestration system. Background Technology

[0002] Carbon dioxide, a greenhouse gas, is a major contributor to global warming. With rapid socio-economic development, carbon dioxide emissions from industrial production and human activities are increasing daily, and the intensifying greenhouse effect seriously threatens climate balance and the ecological environment. How to effectively control and reduce carbon dioxide emissions has become a serious problem facing countries worldwide. Besides reducing the direct use of carbon-based energy, CO2 geological sequestration is another way to reduce carbon dioxide emissions. It involves capturing CO2 from energy-intensive industrial sources such as coal-fired power plants and metallurgy, and then injecting it into deep geological structures (deep earth, seabed, depleted oil and gas reservoirs, etc.) to preserve CO2, avoiding direct emission of carbon dioxide into the atmosphere. This is an important development direction in the field of carbon dioxide emission reduction and greenhouse gas treatment. Among these technologies, hydrate-based CO2 sequestration is a cutting-edge geological sequestration technique. It injects CO2 into water-bearing geological structures with suitable thermodynamic conditions to form solid CO2 hydrates within the porous medium. Due to the high carbon storage density and excellent mechanical properties of CO2 hydrates, this technology can achieve stable and long-term CO2 sequestration.

[0003] However, hydrate-based CO2 sequestration technology still faces bottlenecks before large-scale application. First, the formation of CO2 hydrates requires stringent thermodynamic conditions. CO2 hydrates are difficult to stably store in high-temperature geological structures, resulting in slow formation kinetics and ultimately limiting the amount of CO2 that can be stored. These issues necessitate the search for and development of efficient and environmentally friendly hydrate thermodynamic promoters to improve the thermodynamic conditions and kinetics of CO2 hydrate formation and enhance the carbon storage capacity of geological structures. Furthermore, gas-liquid seepage and component diffusion within porous geological media can cause heterogeneous distribution of hydrate promoters, making them less miscible with water and CO2, hindering efficient CO2 hydrate sequestration, and even causing chemical reagent diffusion and environmental pollution. Therefore, new engineering methods are needed to maximize the use of hydrate promoters injected into the formation, enabling efficient CO2 sequestration and reducing raw material waste and environmental pollution. Summary of the Invention

[0004] To address the aforementioned technical problems, this invention provides a carbon dioxide sequestration method and system, which utilizes a thermodynamic and kinetic dual promoter, 1,3-dioxolane, to achieve carbon dioxide sequestration in large-scale scenarios, realizing efficient, rapid, and environmentally friendly CO2 geological sequestration.

[0005] To achieve the above objectives, the technical solution adopted by the present invention is as follows:

[0006] On one hand, the present invention provides a carbon dioxide sequestration method, the carbon dioxide sequestration method comprising the following steps:

[0007] (1) Inject an aqueous solution of 1,3-dioxolane into the target geological area;

[0008] (2) Inject the gas to be sealed into the target geological area and generate carbon dioxide hydrate through reaction.

[0009] In a preferred embodiment, in step (2), after the gas to be sealed is injected, the pressure difference between the target geological area and the initial pressure is ≤1.0MPa;

[0010] In some specific implementations, the operation of injecting the gas to be sealed into the target geological area in step (2) is repeated multiple times; specifically, after carbon dioxide hydrate is generated by the reaction, the pressure in the target geological area is 3.0 MPa lower than the original formation pressure, and the operation of injecting the gas to be sealed into the target geological area is repeated.

[0011] Preferably, in step (2), before injecting the gas to be sealed, the process further includes a diffusion stage of the 1,3-dioxolane aqueous solution;

[0012] Preferably, in the final repeated injection of the gas to be sealed into the target geological area, a continuous gas injection method is used to maintain the pressure in the target geological area at the initial formation pressure (±0.5MPa) for 6-12 months. In the technical solution of the present invention, continuous gas injection causes phase separation of the unused 1,3-dioxolane aqueous solution in the target geological area, so that the aqueous solution phase rich in 1,3-dioxolane can further seal carbon dioxide in liquid phase.

[0013] As a preferred embodiment, it also includes post-processing, wherein the post-processing is to solidify the target geological area;

[0014] Preferably, the target geological area is sealed after the pressure in the target geological area is not lower than the initial pressure and has stabilized.

[0015] In some specific embodiments, the target geological area is an aquifer, submarine strata, or aquifer abandoned oil and gas reservoir with suitable thermodynamic conditions for the formation of carbon dioxide hydrate.

[0016] Preferably, the highest temperature within the target geological area does not exceed 15°C;

[0017] Preferably, the initial pressure within the target geological area is not less than 2.5 MPa.

[0018] In some specific implementations, the target geological area should meet the following characteristics: large internal space, large porosity, low permeability and well-sealed boundaries, few historical earthquakes, and low seismic intensity.

[0019] Preferably, the porosity is ≥38%.

[0020] In some specific implementations, the target geological area should meet the requirement of having suitable pore water conditions;

[0021] Preferably, the water saturation in the target geological area is not less than 30% and not more than 50%; if it exceeds this range, liquid injection or water pumping operations can be carried out to leave sufficient pore space for subsequent liquid injection and carbon injection, and to reserve enough raw material water for the subsequent formation of carbon dioxide hydrate.

[0022] In a preferred embodiment, the concentration of the injected 1,3-dioxolane aqueous solution in the target geological area is not less than 19.5 wt%.

[0023] Preferably, the purity of carbon dioxide in the gas to be sealed is ≥80 mol%.

[0024] In the technical solution of the present invention, the impurity gas in the gas to be sealed can be any one or more of nitrogen, oxygen and sulfur dioxide.

[0025] In another aspect, the present invention provides a carbon dioxide sequestration system for operating the above-described carbon dioxide sequestration method; the carbon dioxide sequestration system includes a monitoring unit, a conveying unit, and a hydration reaction unit; the conveying unit and the hydration reaction unit are connected together;

[0026] The delivery unit includes a horizontal liquid injection well and a horizontal gas injection well;

[0027] The monitoring unit includes horizontal monitoring wells.

[0028] In the technical solution of the present invention, the horizontal injection well is used to inject or pump fluid into the hydration reaction unit, and the injection includes injecting a 1,3-dioxolane aqueous solution.

[0029] In the technical solution of the present invention, the horizontal gas injection well is used to inject gas into the hydration reaction unit, and the gas injection includes injecting gas to be sealed.

[0030] Preferably, the horizontal injection wells, horizontal monitoring wells, and horizontal gas injection wells are arranged vertically from top to bottom and extend into the interior of the hydration reaction unit.

[0031] Preferably, the monitoring unit includes a monitoring device, which is installed in the horizontal section of the horizontal injection well, the horizontal monitoring well, and the horizontal gas injection well. The monitoring device includes a temperature sensor and a pressure sensor.

[0032] Preferably, it further includes a storage unit; the storage unit includes a gas storage unit and a liquid storage unit; the gas storage unit is connected to the input end of the horizontal gas injection well and is used to store the gas to be sealed; the liquid storage unit is connected to the input end of the horizontal liquid injection well and is used to store a 1,3-dioxolane aqueous solution.

[0033] Preferably, the system further includes a power unit; the power unit includes an air injection pump and a liquid injection pump; the air injection pump is connected to the gas storage unit and is used to provide power for the gas storage unit to deliver gas to the hydration reaction unit through the horizontal air injection well; the liquid injection pump is detachably connected to the liquid storage unit and is used to provide power for the liquid storage unit to deliver liquid to the hydration reaction unit through the horizontal liquid injection well or to provide power for pumping liquid from the hydration reaction unit through the horizontal liquid injection well.

[0034] In the technical solution of the present invention, the horizontal monitoring well is used to monitor the pressure, temperature, porosity, water saturation, resistivity and hydrate saturation in the hydration reaction unit, and to determine the formation location of carbon dioxide hydrate based on the evolution of temperature, pressure and resistivity, so as to provide directional guidance for subsequent gas injection.

[0035] The above technical solution has the following advantages or beneficial effects:

[0036] This invention provides a carbon dioxide sequestration method and system, using 1,3-dioxolane as a promoter in large-scale formation sequestration scenarios for carbon dioxide injection and sequestration. On one hand, 1,3-dioxolane can increase the theoretical reserves of carbon dioxide sequestration using the hydrate method, thereby increasing the solid-phase sequestration capacity of carbon dioxide. On the other hand, the 1,3-dioxolane + carbon dioxide + water system separates into a 1,3-dioxolane-rich phase and a water-rich phase under high-pressure formation conditions, with significant differences in carbon dioxide solubility between the two. Therefore, this invention can adjust the injection of carbon dioxide and 1,3-dioxolane according to different formation conditions such as temperature, pressure, and water saturation, thereby increasing the liquid-phase sequestration capacity of carbon dioxide while reducing chemical diffusion and mitigating the environmental impact of promoter use, ultimately achieving efficient, rapid, and environmentally friendly CO2 geological sequestration.

[0037] Compared with the prior art, the present invention has the following advantages:

[0038] 1. In large-scale formation sequestration scenarios, the injection of 1,3-dioxolane directly enhances the thermodynamic performance of CO2 hydrate formation in pores. Secondly, the 1,3-dioxolane-rich phase, induced by high formation pressure, exhibits strong CO2 dissolving capacity, further increasing the amount of CO2 sequestrated in the geological liquid phase. This novel process in large-scale sequestration scenarios not only comprehensively improves CO2 sequestration but also allows for flexible adjustment of the CO2 and 1,3-dioxolane injection and sequestration schemes according to the characteristics of different formations, ultimately achieving efficient, rapid, and environmentally friendly CO2 geological sequestration.

[0039] 2.1 The injection of 1,3-dioxolane can improve the thermodynamic performance of carbon dioxide hydrate formation, thereby increasing the carbon dioxide sequestration rate and capacity. 1,3-dioxolane itself has strong carbon dioxide solubility, allowing for a larger injection volume per injection compared to conventional sequestration during engineering operations, improving injection efficiency and reducing engineering costs. Theoretically, all injected 1,3-dioxolane can be used for carbon dioxide sequestration; a portion acts as a guest molecule in the carbon dioxide hydrate cage to assist carbon dioxide absorption, while the remaining liquid phase rich in 1,3-dioxolane can also serve as a highly carbon dioxide-soluble liquid phase sequestration carrier, resulting in extremely high raw material utilization. The enrichment of 1,3-dioxolane in the remaining liquid phase reduces the concentration of chemical reagents in the remaining water, mitigating the diffusion of chemical reagents outside the sequestration area, which is more environmentally friendly.

[0040] 3. The addition of thermodynamic promoters reduces the thermodynamic conditions required for the formation of carbon dioxide hydrates, which allows for a wider range of storage sites, fewer restrictions, and easier engineering operations.

[0041] 4. The installation of horizontal wells can artificially accelerate the diffusion and seepage of carbon dioxide in the formation, allowing it to mix more thoroughly with formation water and promoter solutions, thereby increasing the conversion rate of carbon dioxide hydrates and the earliest amount of carbon dioxide stored.

[0042] 5. This invention expands the scope of application of carbon dioxide hydrate sequestration, especially in high-temperature strata in the East my country Sea and South China Sea, as well as in abandoned oil and gas and natural gas hydrate reservoirs, where efficient carbon dioxide sequestration can be achieved, which has significant market value in the fields of carbon sequestration and carbon trading. Attached Figure Description

[0043] Figure 1 This is a schematic diagram of the carbon dioxide storage system in Embodiment 1 of the present invention.

[0044] Figure 2 This is a process flow diagram of carbon dioxide sealing in Embodiments 2-3 of the present invention. Detailed Implementation

[0045] The following embodiments are merely some, not all, of the embodiments of the present invention. Therefore, the detailed descriptions of the embodiments provided below are not intended to limit the scope of the claimed invention, but merely to illustrate selected embodiments. All other embodiments obtained by those skilled in the art based on the embodiments of the present invention without inventive effort are within the scope of protection of the present invention.

[0046] In this invention, unless otherwise specified, all equipment and raw materials are commercially available or commonly used in the industry. The methods described in the following embodiments are conventional methods in the art, unless otherwise specified.

[0047] In the description of this invention, it should be noted that the terms "center", "upper", "lower", "left", "right", "vertical", "horizontal", "inner", "outer", etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings. They are only for the convenience of describing this invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation. Therefore, they should not be construed as limitations on this invention.

[0048] In the description of this invention, it should be noted that, unless otherwise explicitly specified and limited, the terms "installation," "connection," and "joining" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection, a direct connection, or an indirect connection through an intermediate medium; or they can refer to the internal communication between two components. Those skilled in the art can understand the specific meaning of the above terms in this invention based on the specific circumstances.

[0049] Example 1:

[0050] like Figure 1 As shown, this embodiment provides a carbon dioxide storage system, including a monitoring unit, a conveying unit, and a hydration reaction unit 15; the conveying unit and the hydration reaction unit 15 are connected; the conveying unit includes a horizontal injection well 2 and a horizontal gas injection well 1; the monitoring unit includes a horizontal monitoring well 3.

[0051] In this embodiment, a perforation 4 and a packer 5 are provided on the horizontal injection well 2. The opening / closing of the perforation 4 is controlled by the packer 5 to realize the operation of injecting or pumping liquid into the hydration reaction unit 15. The liquid injection includes injecting a 1,3-dioxolane aqueous solution.

[0052] In this embodiment, a gas injection well perforation 6 and a gas injection well packer 7 are provided on the horizontal gas injection well 1. The opening / closing of the gas injection well perforation 6 is controlled by the gas injection well packer 7 to realize the gas injection of the hydration reaction unit 15. The gas injection includes the injection of gas to be sealed.

[0053] Furthermore, the horizontal sections of the injection well 2, monitoring well 3, and gas injection well 1 are distributed vertically from top to bottom and extend into the interior of the hydration reaction unit 15. In the technical solution of the present invention, a target geological area is selected (in this embodiment, the area below seawater 13 is selected as the target sealing area), and the area between the underlayer 16 and the overlayer 14 is designated as the hydration reaction unit 15. The injection well 2 is laid above the hydration reaction unit 15, the monitoring well 3 is laid in the middle, and the gas injection well 1 is laid below.

[0054] Furthermore, the monitoring unit includes a monitoring device, which is installed in the horizontal section of the horizontal injection well 2, the horizontal monitoring well 3 and the horizontal gas injection well 1. The monitoring device includes a temperature sensor and a pressure sensor.

[0055] Furthermore, it also includes a storage unit; the storage unit includes a gas storage unit 8 and a liquid storage unit 10; the gas storage unit 8 is connected to the input end of the horizontal gas injection well 1 and is used to store the gas to be sealed; the liquid storage unit 10 is connected to the input end of the horizontal liquid injection well 2 and is used to store 1,3-dioxolane aqueous solution.

[0056] Preferably, it further includes a power unit 9; the power unit 9 includes an air injection pump 11 and a liquid injection pump 12; the air injection pump 11 is connected to the gas storage unit 8 and is used to provide power for the gas storage unit 8 to deliver gas to the hydration reaction unit 15 through the horizontal air injection well 1; the liquid injection pump 12 is detachably connected to the liquid storage unit 10 and is used to provide power for the liquid storage unit 10 to deliver liquid to the hydration reaction unit 15 through the horizontal liquid injection well 2 or to provide power for pumping liquid from the hydration reaction unit 15 through the horizontal liquid injection well 2.

[0057] In the technical solution of the present invention, the horizontal monitoring well 3 is used to monitor the pressure, temperature, porosity, water saturation, resistivity and hydrate saturation in the hydration reaction unit 15, and to determine the formation location of carbon dioxide hydrate based on the evolution of temperature, pressure and resistivity, so as to provide directional guidance for subsequent gas injection.

[0058] Example 2:

[0059] The actual target geological area selected in this embodiment has an average temperature of 11.0℃, an average pressure of 3.0MPa, and a water saturation of 25%. Without the injection of 1,3-dioxolane, carbon dioxide cannot be injected to form carbon dioxide hydrate.

[0060] This embodiment uses the storage system from Embodiment 1 to perform carbon dioxide sequestration in the aforementioned target geological area, such as... Figure 2 As shown, the steps are as follows:

[0061] After the target geological area is selected, according to Figure 1 The corresponding equipment is laid as shown; based on the water saturation measured by the monitoring device being below 30%, injection is performed through horizontal injection well 2 until the water saturation is below 30%; a 39.5wt% 1,3-dioxolane aqueous solution is injected into the hydration reaction unit 15 through horizontal injection well 2, and the packer 5 of horizontal injection well 2 is opened. After the water saturation of the hydration reaction unit 15 increases to 30%, the average concentration of the 1,3-dioxolane solution in the hydration reaction unit 15 reaches 19.5wt%; the packer 5 of horizontal injection well 2 is closed, allowing the 1,3-dioxolane solution to diffuse evenly downwards; subsequently, carbon dioxide gas to be sealed is injected through horizontal gas injection well 1, and the packer 7 of the gas injection well is opened, waiting for the water to be sealed. After the average pressure in the hydration reaction unit 15 increases to 4.0 MPa, the average pressure gradually decreases as carbon dioxide hydrates are generated in the target area. Based on the changes in the saturation of the liquid, gas, and hydrate phases at different locations measured by the monitoring device, the packers near locations with low hydrate saturation or high liquid saturation are opened to directionally inject carbon dioxide gas, increasing the amount of carbon dioxide hydrate generated at these locations. After continuous gas injection and generation, when the average pressure of the hydration reaction unit 15 gradually stabilizes at around 3.0 MPa, gas injection is stopped, and the horizontal injection well 1 is closed. At this point, the carbon dioxide hydrate storage capacity of the hydration reaction unit 15 is basically at its maximum.

[0062] In this embodiment, 1,3-dioxolane improves the thermodynamic conditions of the hydrate in the sealing region 15, so that carbon dioxide is mainly sealed in the pores in the form of hydrate. The remaining 1,3-dioxolane solution also seals a small amount of carbon dioxide by dissolving it, and the system is not in a state of obvious phase separation in the end.

[0063] Example 3:

[0064] The actual target geological area selected in this embodiment has an average temperature of 11.0℃, an average pressure of 6.0MPa, and a water saturation of 70%. Without the injection of 1,3-dioxolane, carbon dioxide cannot be injected to form carbon dioxide hydrate.

[0065] This embodiment uses the storage system from Embodiment 1 to perform carbon dioxide storage in the aforementioned target geological area. The steps are as follows:

[0066] After the target geological area is selected, according to Figure 1The corresponding equipment is laid as shown; based on the water saturation measured by the monitoring device being greater than 50%, the injection well packer 5 is opened, and water is pumped and depressurized through the horizontal injection well 2 until the water saturation drops to 40% and the average pressure drops to 3.0 MPa; then, a 1,3-dioxolane aqueous solution with a concentration of 54.9 wt% is injected to increase the water saturation of the hydration reaction unit 15 to 50%, so that the average 1,3-dioxolane solution concentration of the hydration reaction unit 15 reaches 19.5 wt%; the injection well packer 5 is closed, and the 1,3-dioxolane solution is allowed to diffuse evenly downwards; then, carbon dioxide gas is injected through the horizontal gas injection well 1, and the gas injection well packer 7 is opened. When the average pressure of the hydration reaction unit 15 increases to 4.0 MPa, the well is shut off, and the gas injection well packer 7 is closed. Subsequently, the average pressure of the hydration reaction unit 15 gradually decreases, and carbon dioxide hydrate is generated. The saturation changes of the liquid, gas, and hydrate phases at different locations within the hydration reaction unit 15 were monitored. For locations with low hydrate saturation or high liquid saturation, the packers near these locations were opened, and carbon dioxide gas was injected directionally to increase the amount of carbon dioxide hydrate generated at these locations. After continuous gas injection and generation, the average pressure of the hydration reaction unit 15 gradually stabilized at around 3.0 MPa. At this point, the carbon dioxide hydrate storage capacity of the hydration reaction unit 15 was essentially reached its limit. Subsequently, carbon dioxide gas was continuously pressurized and injected into the injection well 1 until the pressure reached 6 MPa. Figure 2 At this point, the remaining 1,3-dioxolane in the hydration reaction unit gradually aggregates and transforms into a 1,3-dioxolane-rich phase with strong carbon dioxide dissolution capacity, which makes the hydration reaction unit have a stronger carbon dioxide sequestration capacity.

[0067] In this embodiment, 1,3-dioxolane improved the thermodynamic conditions of the hydrate in hydration reaction unit 15, allowing carbon dioxide to be primarily stored in the pores as a hydrate. The remaining 1,3-dioxolane solution also underwent phase separation, transforming into a 1,3-dioxolane-rich phase with strong carbon dioxide dissolving ability. Figure 2 This not only avoids the diffusion of chemical substances, but also gives the system a dual carbon dioxide sequestration effect of hydrate and liquid phases, reducing raw material waste.

[0068] The above description is only a preferred embodiment of the present invention. It should be noted that for those skilled in the art, several improvements and modifications can be made without departing from the principle of the present invention, and these improvements and modifications should also be considered within the scope of protection of the present invention.

Claims

1. A method for carbon dioxide sequestration, characterized in that, The carbon dioxide sequestration method includes the following steps: (1) Inject an aqueous solution of 1,3-dioxolane into the target geological area; (2) Inject the gas to be sealed into the target geological area and generate carbon dioxide hydrate through reaction; The target geological area is a water-bearing strata, submarine strata, or water-bearing abandoned oil and gas reservoirs with suitable thermodynamic conditions for the formation of carbon dioxide hydrates. The highest temperature within the target geological area shall not exceed 15℃; The initial pressure within the target geological area shall not be less than 2.5 MPa; The porosity of the target geological area is ≥38%; The water saturation level within the target geological area shall be no less than 30% and no more than 50%. The concentration of the injected 1,3-dioxolane aqueous solution within the target geological area shall not be less than 19.5 wt%. In step (2), after the gas to be sealed is injected, the pressure difference between the target geological area and the initial pressure is ≤1.0MPa; The operation of injecting the gas to be sealed into the target geological area in step (2) is repeated multiple times; specifically, after the carbon dioxide hydrate is generated by the reaction, the pressure in the target geological area is 3.0 MPa lower than the original formation pressure, and the operation of injecting the gas to be sealed into the target geological area is repeated. In step (2), before the gas to be sealed is injected, there is also a diffusion stage of the 1,3-dioxolane aqueous solution; In the final repeated injection of the gas to be sealed into the target geological area, a continuous injection method is used to maintain the pressure in the target geological area at the initial formation pressure ±0.5 MPa for 6 to 12 months.

2. The carbon dioxide sequestration method according to claim 1, characterized in that, It also includes post-processing, which involves solidifying the target geological area.

3. The carbon dioxide sequestration method according to claim 2, characterized in that, Once the pressure in the target geological area is not lower than the initial pressure and has stabilized, the target geological area is sealed off.

4. The carbon dioxide sequestration method according to claim 1, characterized in that, The purity of carbon dioxide in the gas to be sealed is ≥80 mol.

5. A carbon dioxide sequestration system for operating the carbon dioxide sequestration method according to any one of claims 1-4, characterized in that, The carbon dioxide sequestration system includes a monitoring unit, a transport unit, and a hydration reaction unit; the transport unit and the hydration reaction unit are connected. The delivery unit includes a horizontal liquid injection well and a horizontal gas injection well; The monitoring unit includes a horizontal monitoring well; The horizontal injection wells, horizontal monitoring wells, and horizontal gas injection wells are arranged vertically from top to bottom and extend into the interior of the hydration reaction unit.

6. The carbon dioxide sequestration system according to claim 5, characterized in that, The monitoring unit includes a monitoring device, which is installed in the horizontal section of the horizontal injection well, the horizontal monitoring well, and the horizontal gas injection well. The monitoring device includes a temperature sensor and a pressure sensor.

7. The carbon dioxide sequestration system according to claim 5, characterized in that, It also includes a storage unit; the storage unit includes a gas storage unit and a liquid storage unit; the gas storage unit is connected to the input end of the horizontal gas injection well and is used to store the gas to be sealed; the liquid storage unit is connected to the input end of the horizontal liquid injection well and is used to store 1,3-dioxolane aqueous solution.

8. The carbon dioxide sequestration system according to claim 7, characterized in that, It also includes a power unit; the power unit includes an air injection pump and a liquid injection pump; the air injection pump is connected to the gas storage unit and is used to provide power for the gas storage unit to deliver gas to the hydration reaction unit through the horizontal air injection well; the liquid injection pump is detachably connected to the liquid storage unit and is used to provide power for the liquid storage unit to deliver liquid to the hydration reaction unit through the horizontal liquid injection well or to provide power for pumping liquid from the hydration reaction unit through the horizontal liquid injection well.

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