A method for sand prevention in injection and production of a salt cavern gas storage

Abstract

The application discloses a kind of sediment salt cavern gas storage injection sand prevention methods, it is related to underground salt cavern gas storage operation maintenance field, including steps: the spray pipe is entered into the preset height at injection and production wellhead;Between the annular position of the outer wall of spray pipe and the inner wall of injection and production string packer is sealed and sealed;Rotary drive unit is started, and the rotary spray head of spray pipe and its lower end is uniformly rotated around spray pipe axis;Consolidation chemical agent is pumped into spray pipe from ground at set flow and pressure, and consolidation chemical agent is output through the spray hole of rotary spray head, and uniformly sprayed on sediment surface;Sprayed consolidation chemical agent makes loose sediment particles consolidate in situ into porous medium with overall strength;Stop injecting consolidation chemical agent, and maintain for a set period of time;Unseal packer, and spray pipe and rotary spray head are pulled up to wellhead, and one sand prevention operation is completed.The application can inhibit particle starting from sediment source, and can adapt to the complex working condition of alternating gas flow during injection and production operation.

Description

Technical Field

[0001] This invention relates to the field of operation and maintenance technology for underground salt cavern gas storage facilities, and in particular to a method for preventing sand from entering and exiting a sediment salt cavern gas storage facility. Background Technology

[0002] Utilizing salt caverns formed by water-soluble cavitation in underground salt rock deposits as gas storage spaces is an important development direction for compressed air energy storage, natural gas storage, and underground hydrogen storage, offering significant advantages such as large storage capacity, high safety performance, long service life, and environmental friendliness. During the water-soluble cavitation process and brine extraction, insoluble mineral impurities from within the salt rock continuously precipitate and deposit at the bottom of the cavity, forming a loose sediment layer up to tens of meters thick. This sediment layer is a porous medium with no effective bonding between particles, resulting in a loose and easily disturbed overall structure.

[0003] During the injection and production operation of a salt cavern gas storage facility, when high-speed gas flow enters the cavity through the injection / production tubing or exits the cavity and enters the injection / production tubing, a high-intensity vortex flow field is formed in the transition area between the wellbore and the cavity due to the abrupt change in the cross-sectional area of ​​the flow channel and the superimposed effects of gas expansion and compression. This vortex flow field directly acts on the surface of the sediment at the bottom of the cavity, causing originally stationary sediment particles to start, suspend, and enter the wellbore with the gas flow. Ultimately, these particles are carried to the surface system, causing a series of problems such as wear on surface filtration equipment, blockage of gathering and transmission pipelines, and reduced injection and production efficiency, posing a serious threat to the long-term safe and stable operation of the gas storage facility.

[0004] Regarding the sediment problem in salt cavern gas storage facilities, existing technological research and engineering applications mainly focus on brine drainage and sand control during the construction phase. Furthermore, previous studies have revealed the flow patterns of brine and sediment particles during gas-driven drainage through indoor simulation experiments, analyzed the changes in particle velocity and sand output near the drainage pipe under different nitrogen displacement pressures, and proposed a sand control approach using screen pipes. However, these studies all revolve around the brine drainage process during the construction phase, and the proposed screen pipe sand control still falls under the category of passive interception technology. It can only intercept already activated particles in the fluid channel, failing to inhibit particle activation at the source of sediment, and is difficult to adapt to the complex operating conditions of alternating airflow during injection and production.

[0005] There is an urgent need to design a technical solution that can suppress particle initiation from the source of sediment and adapt to the complex working conditions of alternating airflow during injection and production. Summary of the Invention

[0006] The purpose of this invention is to provide a method for preventing sand in injection and production in a sediment salt cavern gas storage facility, in order to solve the problems existing in the prior art. This method can suppress particle initiation from the source of sediment and can adapt to the complex working conditions of alternating airflow during injection and production.

[0007] To achieve the above objectives, the present invention provides the following solution: This invention provides a method for sand control during injection and production in a sediment salt cavern gas storage facility, comprising the following steps: The spray pipe with a rotating spray head connected to its lower end is lowered into the injection and production string through the injection and production wellhead until the rotating spray head reaches a preset height above the sediment surface at the bottom of the cavity. A sealing packer is installed in the annulus between the outer wall of the spray pipe and the inner wall of the injection / production tubing to block the upward flow of chemicals along the annulus. Start the rotary drive unit to make the rotary spray head rotate at a constant speed around the axis of the spray pipe; The solidification chemical agent is pumped from the ground into the spray pipe at a set flow rate and pressure. The solidification chemical agent is output through the nozzle of the rotating spray head and sprayed evenly on the surface of the sediment, forming a continuous circumferential coverage trajectory. The sprayed solidification chemical agent penetrates into the shallow interior of the sediment and forms bonding bridges between sediment particles through physical adsorption, chemical bonding or hydration reaction, so that the loose sediment particles are solidified in situ into a porous medium with overall strength. Stop injecting consolidation chemicals, maintain the wellbore in a sealed state for the set curing time, and allow the consolidation reaction to proceed fully; Unseal the packer, pull up the spray pipe and rotate the spray head to the wellhead to complete one sand control operation.

[0008] In one embodiment, the preset height between the rotating spray head and the sediment surface is 20~30m.

[0009] In one embodiment, the rotational speed of the rotary spray head is 0.5~10 r / min.

[0010] In one embodiment, the injection flow rate of the consolidation chemical is 0.5~5.0 m. 3 / h, injection pressure is 0.5~2.0MPa; the coverage radius of a single spraying operation on the sediment surface is 5~20m.

[0011] In one embodiment, the nozzles of the rotary spray head are evenly distributed circumferentially, and the spray angle of the rotary spray head can be adjusted so that the solidification chemical jet forms an angle of 30° to 60° with the sludge surface.

[0012] In one embodiment, the penetration and consolidation depth of the consolidation chemical agent in the sediment is 0.1~0.5m.

[0013] In one embodiment, the consolidating chemical agent is at least one of water-soluble resin, water glass, cement-based slurry, and polymer solution; the viscosity of the consolidating chemical agent is 50~500 mPa·s.

[0014] In one embodiment, the sealing packer is an expandable packer, and its setting position is located above the top boundary of the salt layer. After the sealing packer is set, it can withstand the pressure difference between the injection and production operating pressure and the solidification chemical injection pressure.

[0015] In one embodiment, the spray pipe is made of a corrosion-resistant alloy material, the outer diameter of the spray pipe is smaller than the inner diameter of the injection-production tubing, and an annular channel is formed between the spray pipe and the injection-production tubing; the upper end of the spray pipe is connected to the chemical injection pipeline on the ground through a rotary joint.

[0016] In one embodiment, a production casing is fitted outside the injection-production tubing string, and a surface casing is fitted outside the production casing. The surface casing is fixedly and sealed to the well wall of the injection-production well. The inner wall below the production casing is fixedly and sealed to the outer wall of the injection-production tubing through a first sealing device, and the inner wall below the surface casing is fixedly and sealed to the outer wall of the production casing through a second sealing device.

[0017] The present invention achieves the following technical effects compared to the prior art: This invention addresses the problem of particle carryover at its source, transforming passive interception into active consolidation. Existing sand control technologies passively intercept initiated particles using screens or similar structures at the wellbore or pipe inlet, failing to prevent particles from being initiated from the sediment surface. This invention, by spraying a consolidating chemical agent in situ onto the sediment surface, consolidates loose particles into a porous medium with overall strength, fundamentally eliminating the conditions for particles to be swept up by airflow vortices. The spray pipe of this invention is lowered and raised using existing injection and production tubing, requiring no additional drilling, well completion, or wellbore structure modifications. The operation can be carried out during injection-production intervals or low-flow periods, with minimal impact on the normal injection-production cycle of the gas storage facility. Compared to other sand control methods, this invention can be repeatedly implemented according to changes in the sediment surface during operation, exhibiting strong adaptability. By adjusting the chemical agent viscosity, injection flow rate, and spray height, the depth of the consolidation layer can be controlled within the shallow surface of the sediment, ensuring that the consolidation layer possesses sufficient particle bonding strength while retaining the porous permeability of the sediment, without affecting the effective gas storage volume and injection-production efficiency of the cavity. Attached Figure Description

[0018] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0019] Figure 1 This is a schematic diagram illustrating the working state of the sand control system for the sediment salt cavern gas storage injection and production system in one or more embodiments of the present invention. Figure 2This is a schematic diagram of the sand control process for the injection and extraction of a sediment salt cavern gas storage facility in one or more embodiments of the present invention.

[0020] In the diagram: 1-Spray pipe, 2-Rotary spray head, 3-Sealing packer, 4-Injection and production tubing, 5-Production casing, 6-Surface casing, 7-Cavity, 8-Settling surface, 9-Rotary drive unit, 10-Chemical reagent storage tank. Detailed Implementation

[0021] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0022] The purpose of this invention is to provide a method for preventing sand in injection and production in a sediment salt cavern gas storage facility, in order to solve the problems existing in the prior art. This method can suppress particle initiation from the source of sediment and can adapt to the complex working conditions of alternating airflow during injection and production.

[0023] To make the above-mentioned objects, features and advantages of the present invention more apparent and understandable, the present invention will be further described in detail below with reference to the accompanying drawings and specific embodiments.

[0024] This invention provides a method for sand control during injection and production in a sediment salt cavern gas storage facility. This method employs a sediment salt cavern gas storage facility injection and production sand control system, such as... Figure 1 As shown, the system includes a spray pipe 1 and a rotary spray head 2. The spray pipe 1 can extend into the well via an injection-production tubing 4. A sealing packer 3 is installed on the inner wall of the injection-production tubing 4. After the sealing packer 3 is set, it can seal the spray pipe 1 to the inner wall of the injection-production tubing 4. The sealing packer 3 is an expandable packer, and its setting position is located above the top boundary of the salt layer. It is used to seal the annulus during spraying operations to prevent the chemical agent from flowing back up along the annulus and to prevent the injection-production gas from leaking. After the sealing packer 3 is set, it can withstand the injection-production operating pressure and consolidation. The pressure difference between the chemical injection pressures; the production casing 5 is sleeved on the outside of the injection-production tubing string 4; the surface casing 6 is sleeved on the outside of the production casing 5; the surface casing 6 is fixedly and sealed to the well wall of the injection-production well; the inner wall below the production casing 5 is fixedly and sealed to the outer wall of the injection-production tubing through a first sealing device; the inner wall below the surface casing 6 is fixedly and sealed to the outer wall of the production casing 5 through a second sealing device; existing wellhead devices can be used to fix the injection-production tubing string 4, the production casing 5, and the surface casing 6.

[0025] This method recognizes that airflow vortexes during operation are a key mechanism for sediment particle carrying and proposes a targeted technical solution to block this mechanism through in-situ consolidation on the sediment surface. By adjusting the viscosity of the consolidation chemical, the injection flow rate, and the spraying height, the penetration depth of the consolidation chemical in the sediment can be controlled, ensuring that the consolidation layer has sufficient particle bonding strength while retaining the sediment's porosity and permeability, without affecting the effective gas storage volume and injection-production efficiency of cavity 7. This method is not only applicable to compressed air energy storage facilities in salt caverns but can also be applied to underground storage facilities with similar sediment carrying risks, such as natural gas salt cavern gas storage facilities and salt cavern hydrogen storage facilities. The method involves inserting a spray pipe 1 into the injection-production tubing 4, extending the lower end of the spray pipe 1 above the sediment surface 8 of cavity 7. Under rotational drive, the consolidation chemical is uniformly sprayed onto the sediment surface and shallow layer, causing loose particles to be in-situ consolidated into a porous medium with a certain strength, thus forming a consolidation zone. This fundamentally eliminates the conditions for particles to be swirled up by vortices, achieving a technological leap from passive interception to active consolidation. This method can be implemented without interrupting normal injection and production operations, and can be repeated based on changes in the sediment surface, effectively ensuring the long-term safe and stable operation of the gas storage facility. Figure 2As shown, the specific steps of this method are as follows: S1, the spray pipe 1, with the rotating spray head 2 connected to its lower end, is lowered into the injection-production tubing string 4 through the injection-production wellhead until the rotating spray head 2 reaches a preset height above the sediment surface 8 at the bottom of the cavity 7; S2, a sealing packer 3 is set at the annulus position between the outer wall of the spray pipe 1 and the inner wall of the injection-production tubing string 4 to block the channel for the chemical agent to flow back upward along the annulus; S3, the rotary drive unit 9 on the ground is started, which drives the spray pipe 1 and the rotating spray head 2 at its lower end to rotate uniformly around the axis of the spray pipe 1 through the rotary joint; S4, the solidification chemical agent is pumped into the spray pipe 1 from the ground at a set flow rate and pressure; S5, the solidification chemical agent is output through the nozzle of the rotating spray head 2, forming a solidification agent on the horizontal surface. The fan-shaped or ring-shaped spray trajectory is evenly sprayed onto the surface of the sediment, forming a continuous circumferential coverage trajectory. The tilt angle of the rotating spray head 2 is adjustable, so that the solidification chemical jet is at a certain angle to the sediment surface 8 to increase the contact area with the sediment and promote penetration. S6, the sprayed solidification chemical penetrates into the shallow interior of the sediment, forming bonding bridges between sediment particles through physical adsorption, chemical bonding, or hydration reaction, so that the loose sediment particles are solidified in situ into a porous medium with overall strength. S7, the injection of solidification chemical is stopped, and the wellbore is kept in a sealed state for a set time to allow the solidification reaction to proceed fully. S8, the sealing packer 3 is released, and the spray pipe 1 and rotating spray head 2 are pulled up to the wellhead to complete one sand control operation. This invention addresses the particle-carrying problem at its source, transforming passive interception into active consolidation. Existing sand control technologies passively intercept initiated particles using screens or similar structures at the wellbore or pipe inlet, failing to prevent particles from being initiated from the sediment surface 8. This invention, by spraying a consolidating chemical agent in situ onto the sediment surface, consolidates loose particles into a porous medium with overall strength, fundamentally eliminating the conditions for particles to be swept up by airflow vortices. The spray pipe 1 of this invention is lowered and raised using the existing injection-production tubing 4, requiring no additional drilling, well completion, or wellbore structure modification. The operation can be carried out during injection-production intervals or low-flow periods, with minimal impact on the normal injection-production cycle of the gas storage facility. Compared to other sand control methods, this invention can be repeatedly implemented based on changes in the sediment surface 8 during operation, exhibiting strong adaptability. By adjusting the chemical agent viscosity, injection flow rate, and spray height, the depth of the consolidation layer can be controlled within the shallow surface of the sediment, ensuring the consolidation layer possesses sufficient particle bonding strength while retaining the porous permeability of the sediment, without affecting the effective gas storage volume and injection-production efficiency of the cavity 7.

[0026] In one embodiment, the preset height between the rotary spray head 2 and the sediment surface 8 is 20-30m. The rotary spray head 2 is rotatably connected to the spray pipe 1, and its connection structure adopts existing technology. For example, a snap-fit ​​rotary structure can be used, utilizing the elasticity of the material to connect the rotary spray head 2 and the spray pipe 1 through a snap-fit ​​method, allowing relative rotation; or a bearing-type rotary structure can be used, with built-in rolling bearings (such as ball bearings) or sliding bearings to support the rotating parts, achieving low friction and high precision rotation. The spray pipe 1 is provided with a drive mechanism that is transmitted to the rotary spray head 2. This drive mechanism adopts existing technology structure. For example, a motor can be set on the spray pipe 1, and the motor is connected to the rotary spray head 2 through a worm gear structure to control the rotation process of the rotary spray head 2. In other ways, the motor can be set outside the wellhead, and the motor transmits power to the polished rod through a pulley. The polished rod is set parallel to one side of the spray pipe 1, and the end of the polished rod is connected to the rotary spray head 2, which drives the downhole rotary spray head 2 to rotate. The rotation speed of the rotary spray head 2 is 0.5~10 r / min. In this embodiment, the rotary spray head 2 has multiple spray holes, which are evenly distributed circumferentially and located on the sidewalls and bottom surface of the rotary spray head 2. Therefore, the coverage area is wider during spraying. Combined with the flow rate and pressure control during spraying, the spraying range is more precise, avoiding omissions. In addition to being able to rotate circumferentially, the tilt angle between the rotary spray head 2 and the spray pipe 1 can be adjusted, so that the spray angle can be adjusted so that the solidification chemical jet forms a tilt angle of 30°~60° with the sludge surface. In this embodiment, the rotary spray head 2 can be hinged to a transfer frame, which is rotatably connected to the spray pipe 1. The drive mechanism drives the transfer frame to rotate around the axis of the spray pipe 1, thereby driving the rotary spray head 2 to rotate synchronously. The tilt angle between the rotary spray head 2 and the transfer frame can be manually adjusted to the required angle before being lowered into the well.

[0027] In another embodiment, the rotating spray head 2 can be fixedly connected to the spray pipe 1, and a rotating drive unit 9 can be installed at the wellhead to drive the spray pipe 1 to rotate. The spray pipe 1 can drive the rotating spray head 2 to rotate synchronously, thus achieving the rotating spraying process. The rotating drive unit 9 can use a reducer motor as a power source, transmitting power to the spray pipe 1 through a sprocket, transmission chain, or other mechanism to make it rotate; or it can use an existing electric rotating unit; or it can use a servo or stepper motor, in conjunction with a planetary reducer or harmonic reducer, to drive the spray pipe 1. For cavities 7 with smaller diameters, the rotating spray head 2 can be replaced with a fixed multi-hole spray head; for cavities 7 with larger diameters, a multi-segment spray pipe 1 or a combined spray head can be used to increase the single-time coverage radius. In addition to being carried out during the injection-production interval, the operation can also be carried out during low-flow injection-production periods, when the airflow disturbance in the cavity 7 is smaller, which is conducive to the uniform sedimentation and penetration of the chemical agent.

[0028] In one embodiment, the spray pipe 1 is made of a corrosion-resistant alloy to resist corrosion from the high-concentration brine and alternating airflow in the salt cavern environment. The outer diameter of the spray pipe 1 is smaller than the inner diameter of the injection-production tubing 4, forming an annular channel between the spray pipe 1 and the injection-production tubing 4. The upper end of the spray pipe 1 is connected to a chemical agent injection pipeline on the ground via a rotary joint. The chemical agent injection pipeline is connected to a chemical reagent storage tank 10 on the ground via a control pump and a control valve. After the control valve is opened, the control pump drives the solidification chemical agent to enter the spray pipe 1 through the chemical agent injection pipeline and spray it out through the rotary spray head 2. The control pump and control valve work together to adjust the injection pressure and flow rate of the solidification chemical agent. Pressure gauges, flow meters, and other flow and pressure monitoring units can be installed at the spray pipe 1 or the rotary spray head 2 to detect the injection pressure and flow rate in real time. The injection flow rate of the solidification chemical agent is 0.5~5.0 m³ / h. 3 / h, injection pressure is 0.5~2.0MPa; the coverage radius of a single spraying operation on the sediment surface 8 is 5~20m; by adjusting the spraying pressure, the penetration and consolidation depth of the solidification chemical agent in the sediment can be 0.1~0.5m.

[0029] In one embodiment, the consolidating chemical agent is at least one of water-soluble resin, water glass, cement-based slurry, and polymer solution; the viscosity of the consolidating chemical agent is 50~500 mPa·s.

[0030] Example 1 This embodiment takes a salt cavern compressed air energy storage gas reservoir as an example. The effective height of the reservoir cavity is approximately 120 m, the sediment thickness is approximately 30 m, the sediment particle size distribution ranges from 0.075 to 40 mm, and the average porosity is approximately 40%. The injection and production operating pressure ranges from 14 to 16 MPa, and the designed injection and production flow rate for a single well is 50 to 200 m³ / h. 3 / min. After multiple injection-production cycles, ground monitoring showed a gradual increase in the amount of deposited particles in the filter, indicating the presence of sediment carryover.

[0031] The operation process of the sediment salt cavern gas storage sand control method in this embodiment is as follows: (1) Preparation stage: Select water-soluble epoxy resin as the solidification chemical agent and prepare a solution with a viscosity of about 200 mPa·s. The storage tank capacity is 10 m 3(2) Lowering stage: The spray pipe 1 (outer diameter 50 mm, inner diameter 40 mm, length 150 m) is slowly lowered from the injection-production wellhead through the injection-production tubing string 4 (inner diameter 309.37 mm). The depth marker is used to confirm that the rotating spray head 2 reaches 25 m above the sediment surface 8. (3) Sealing stage: An expandable packer is set at the annular position between the outer wall of the spray pipe 1 and the inner wall of the injection-production tubing string 4. The setting depth is 10 m above the top boundary of the salt layer to ensure reliable annular sealing. (4) Spraying stage: The ground hydraulic motor is started, and the rotation speed of the spray pipe 1 is set to 2 r / min; the flow rate is 2 m 3 Inject solidifying chemical agent at a pressure of 1.0 MPa per hour. Continue spraying for 5 hours, with a total injection volume of 10 m³. 3 , The chemical agent covers the sediment surface 8 with a radius of about 12 m. (5) Curing stage: Stop injection, keep the wellhead sealed, and cure for 48 h to allow the epoxy resin to fully solidify between the sediment particles. (6) Recovery stage: Unseal the packer in the annulus, slowly lift the spray pipe 1 to the wellhead, and complete the operation.

[0032] Effectiveness Verification: After the operation was completed, injection and production were resumed, and continuous monitoring was conducted for 6 months. Results showed that the particle deposition in the surface filter decreased by approximately 85% compared to before the operation; the pressure drop in the injection and production pipes remained stable without abnormal fluctuations; sonar detection showed that the sediment surface morphology remained stable, with no obvious local collapse or formation of new dominant channels. This verified the effectiveness of the method.

[0033] Specific examples have been used to illustrate the principles and implementation methods of this invention. The descriptions of the above embodiments are only for the purpose of helping to understand the method and core ideas of this invention. Furthermore, those skilled in the art will recognize that, based on the ideas of this invention, there will be changes in the specific implementation methods and application scope. Therefore, the content of this specification should not be construed as a limitation of this invention.

Claims

1. A method for sand control during injection and production in a sediment salt cavern gas storage facility, characterized in that: Includes the following steps: The spray pipe with a rotating spray head connected to its lower end is lowered into the injection and production string through the injection and production wellhead until the rotating spray head reaches a preset height above the sediment surface at the bottom of the cavity. A sealing packer is installed in the annulus between the outer wall of the spray pipe and the inner wall of the injection / production tubing to block the upward flow of chemicals along the annulus. Start the rotary drive unit to make the rotary spray head rotate at a constant speed around the axis of the spray pipe; The solidification chemical agent is pumped from the ground into the spray pipe at a set flow rate and pressure. The solidification chemical agent is output through the nozzle of the rotating spray head and sprayed evenly on the surface of the sludge to form a continuous circumferential coverage trajectory. The sprayed solidification chemical agent penetrates into the shallow interior of the sediment and forms bonding bridges between sediment particles through physical adsorption, chemical bonding or hydration reaction, so that the loose sediment particles are solidified in situ into a porous medium with overall strength. Stop injecting consolidation chemicals, maintain the wellbore in a sealed state for the set curing time, and allow the consolidation reaction to proceed fully; Unseal the packer, pull up the spray pipe and rotate the spray head to the wellhead to complete one sand control operation.

2. The method for sand control during injection and production in a sediment salt cavern gas storage facility according to claim 1, characterized in that: The preset height between the rotating spray head and the sediment surface is 20~30m.

3. The method for sand control during injection and production in a sediment salt cavern gas storage facility according to claim 1, characterized in that: The rotation speed of the rotary spray head is 0.5~10 r / min.

4. The method for sand control during injection and production in a sediment salt cavern gas storage facility according to claim 1, characterized in that: The injection flow rate of the consolidation chemical agent is 0.5~5.0 m. 3 / h, injection pressure is 0.5~2.0MPa; the coverage radius of a single spraying operation on the sediment surface is 5~20m.

5. The method for sand control during injection and production in a sediment salt cavern gas storage facility according to claim 1, characterized in that: The nozzles of the rotary spray head are evenly distributed circumferentially, and the spray angle of the rotary spray head can be adjusted so that the solidification chemical jet forms an angle of 30° to 60° with the sludge surface.

6. The method for sand control during injection and production in a sediment salt cavern gas storage facility according to claim 1, characterized in that: The penetration and consolidation depth of the consolidation chemical agent in the sediment is 0.1~0.5m.

7. The method for sand control during injection and production in a sediment salt cavern gas storage facility according to claim 1, characterized in that: The consolidating chemical agent is at least one of water-soluble resin, water glass, cement-based slurry, and polymer solution; the viscosity of the consolidating chemical agent is 50~500 mPa·s.

8. The method for sand control during injection and production in a sediment salt cavern gas storage facility according to claim 1, characterized in that: The sealing packer is an expandable packer, and its setting position is located above the top boundary of the salt layer. After the sealing packer is set, it can withstand the pressure difference between the injection and production operating pressure and the solidification chemical injection pressure.

9. The method for sand control during injection and production in a sediment salt cavern gas storage facility according to claim 1, characterized in that: The spray pipe is made of corrosion-resistant alloy material. The outer diameter of the spray pipe is smaller than the inner diameter of the injection and production tubing. An annular channel is formed between the spray pipe and the injection and production tubing. The upper end of the spray pipe is connected to the chemical injection pipeline on the ground through a rotary joint.

10. The method for sand control during injection and production in a sediment salt cavern gas storage facility according to claim 1, characterized in that: The injection-production tubing is fitted with a production casing on the outside, and a surface casing is fitted with a surface casing on the outside. The surface casing is fixedly and sealed to the well wall of the injection-production well. The inner wall below the production casing is fixedly and sealed to the outer wall of the injection-production tubing through a first sealing device, and the inner wall below the surface casing is fixedly and sealed to the outer wall of the production casing through a second sealing device.

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