On-site injection-production operation method for relieving water cone of gas storage containing bottom water

Abstract

The invention relates to the technical field of oil and gas storage and transportation, in particular to an on-site injection and production operation method for relieving a water cone of a gas storage with bottom water, which comprises the following steps: during the gas injection period of the gas storage, implementing zoned regulation and control pressure cone water driving operation of manually regulating and controlling the gas injection amount of a single well of the gas storage; a general gas injection mode that all injection and production wells are opened at the same time during gas injection of the gas storage is changed, and differential gas injection pressure cone water driving gas injection is implemented; in the gas production period of the gas storage, zoned and staged water control and production increasing operation is implemented, according to gas storage multi-period injection and production operation historical data, the cumulative injection and production gas quantity ratio of a water flooding and water invasion area single well of bottom water coning and a normal injection and production area single well and the water-liquid ratio in the single well gas production liquid-carrying cumulative liquid production capacity are accurately counted, and a bottom water-containing gas storage plane injection and production imbalance area is determined; the problem that normal injection and production cannot be carried out on a gas storage injection and production well site due to bottom water coning of a bottom water-containing gas storage can be gradually relieved, and the gas storage injection and production well is convenient to operate, low in cost, high in safety performance, environment-friendly and reliable.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas storage and transportation, and particularly relates to a field injection-production operation method for alleviating water coning in a bottom-water-containing gas storage reservoir. Background Art

[0002] During the high-speed injection-production operation of "large injection and large production" of injection-production wells in underground gas storage reservoirs, due to the large gas supply for stage emergency peak shaving, there is a phenomenon of injection-production imbalance (less injection and more production) in the actual on-site operation. If injection-production imbalance (less injection and more production) occurs in a bottom-water-containing gas storage reservoir during actual operation, it is easy to form a bottom-water cone in the production layer, inducing wellbore water flooding and water invasion in the injection-production wells, and ultimately resulting in low efficiency of the on-site injection-production operation of the gas storage reservoir. Considering the strong activity of the bottom water, if the on-site injection-production method is not optimized in time, it is very likely to cause the abandonment of the reservoir due to water flooding, which is more unfavorable to the requirements of the development of the gas storage reservoir business. Currently, the traditional practices in oil and gas development are: chemically or mechanically plugging the water-producing layer of the production well to achieve benign natural gas production; or implementing methods such as reducing the backpressure to induce blowout and liquid drainage and coiled tubing gas lift drainage for the flooded wellbore to restore normal production of the wellbore. These practices have certain positive effects on the single-phase flow development mode of oil wells.

[0003] The invention patent with the application number 202110361692.2 provides a method for controlling bottom-water coning or ridge advancing in an oil well. The method includes the following steps: determining the position, height and volume of the water cone or water ridge and the remaining oil distribution in the oil well according to data, determining the treatment construction position, the volume and area of the artificial chemical partition to be established, and whether to fill holes; injecting a gas into the oil well to depress the height of the water cone or water ridge, and then injecting a first isolation liquid; sequentially injecting CO2 for the first time, a second isolation liquid, an aqueous silicate solution, a third isolation liquid, CO2 for the second time and a kill fluid into the treated oil well, and performing a shut-in treatment to form the artificial chemical partition at the top of the water cone or water ridge at the oil-water interface in the oil well.

[0004] The above method retrieved has guiding significance for solving the problem of bottom-water coning during oil production and improving the degree of oil and gas recovery. However, the on-site injection-production operation mode of the gas storage reservoir is a high-speed two-way natural gas flow process of "large injection and large production" in the injection-production wellbore, which is different from the single-phase flow development mode of oil wells. Therefore, this method is not applicable to the on-site injection-production operation for alleviating water coning in a bottom-water-containing gas storage reservoir, and it has poor operability on site. Summary of the Invention

[0005] The purpose of the present invention is to provide a field injection-production operation method for alleviating water coning in a bottom-water-containing gas storage reservoir, aiming at the problems of water flooding after water coning in the injection-production wells and water invasion in the injection-production process due to the strong activity of the bottom water during the on-site injection-production operation of the bottom-water-containing gas storage reservoir.

[0006] The technical solution of the present invention is realized as follows:

[0007] An embodiment of the present invention provides a field injection-production operation method for alleviating water coning in a bottom-water-containing gas storage reservoir. The method includes: during the gas injection period of the gas storage reservoir, implementing a zonal control pressure cone water drive operation for manually regulating the single-well gas injection volume of the gas storage reservoir, changing the general gas injection method in which all injection-production wells in the gas storage reservoir are opened simultaneously during the gas injection period, and implementing differential gas injection pressure cone water drive gas injection; during the gas production period of the gas storage reservoir, implementing zonal and staged water control and production increase operations, and based on the historical data of multi-cycle injection-production operations of the gas storage reservoir, accurately counting the cumulative injection-production gas volume ratio of single wells in the water flooded and invaded areas where the bottom water cones in and the water-liquid ratio in the cumulative liquid production of single wells in the normal injection-production area, and clarifying the plane injection-production imbalance area of the bottom-water-containing gas storage reservoir.

[0008] In some embodiments, the implementation of differential gas injection pressure cone water drive gas injection includes:

[0009] Temporarily shutting down the gas injection-production wells in the gas storage reservoir with good physical properties and relatively high free gas absorption capacity adjacent to the water flooded wells;

[0010] For the water flooded wells in the gas storage reservoir, injecting gas under pressure through the ground compressor in the gas storage gathering and injection station to achieve pressure cone water drive and restore the gas injection volume of the water flooded wells.

[0011] In some embodiments, the implementation of differential gas injection pressure cone water drive gas injection further includes: in some embodiments, installing an injection throttle valve at the injection pipeline of the production tree of the gas injection-production wells in the gas storage reservoir that have not been water flooded and have a relatively high gas injection volume, and manually controlling the opening of the injection throttle valve at the wellhead to implement differential zonal control type gas injection for water flooded wells, water invaded wells and normal wells, so as to effectively achieve pressure cone for water flooded and invaded wells and optimize the gas injection process flow.

[0012] In some embodiments, the historical data of multi-cycle injection-production operations of the gas storage reservoir includes: accurately calculating the upper limit index of the liquid carrying capacity per ten thousand cubic meters of gas at the water flooding moment of a single well in the bottom-water-containing gas storage reservoir based on the historical data of multi-cycle injection-production operations of the gas storage reservoir.

[0013] In some embodiments, the upper limit index is based on the principle of plane injection-production rebalancing of the bottom-water-containing gas storage reservoir and the liquid carrying capacity per ten thousand cubic meters of gas of a single well being less than the upper limit index of the liquid carrying capacity per ten thousand cubic meters of gas at the water flooding moment of the single well. According to the differences in the original gas-liquid interface of the reservoir and the water avoidance height of each injection-production wellbore, for the injection-production wells in the water invaded area where the bottom water cones in, gentle and stable gas production is mainly adopted, and for the single wells in the normal injection-production area, active production increase and peak shaving gas production are implemented.

[0014] In some embodiments, the historical data of multi-cycle injection-production operations of the gas storage reservoir includes: the liquid carrying capacity per ten thousand cubic meters of gas of each single well, the dynamic monitoring flowing pressure and static pressure values, the gas-liquid interface parameters, and the well stream component analysis data.

[0015] In some embodiments, after obtaining the multi-cycle injection and production operation history data of the gas storage reservoir, the following steps are further included:

[0016] Based on the liquid-carrying capacity per ten thousand cubic meters of gas in each single well, the dynamic monitoring flowing pressure and static pressure values, the gas-liquid interface parameters, and the well stream component analysis data, comprehensively compare and analyze the multi-cycle on-site injection and production operation data of the bottom-water-containing gas storage reservoir, and conduct numerical simulation studies on the collected on-site data for different stages during the gas injection period and the gas production period respectively. According to the correlation between the variation laws of the gas-liquid interface at different stages and the injection and production gas volumes, obtain the reference data for efficient on-site injection and production operation of the bottom-water-containing gas storage reservoir.

[0017] In some embodiments, the gas injection throttle valve is an angle throttle valve, and the type selection and size of the gas injection throttle valve are calculated according to the actual injection and production operation parameters of the gas storage reservoir.

[0018] In some embodiments, the materials and pressure resistance grades of the valve body, valve cover, valve internals, and seals of the gas injection throttle valve meet the working conditions at the installation location of the gas injection pipeline of the Christmas tree of the injection and production well and the environmental requirements of the site.

[0019] The beneficial effects of the embodiments of the present invention are:

[0020] The present application invents a method for on-site injection and production operation of a bottom-water-containing buried hill gas storage reservoir with "injecting to support production and zoning regulation". During the gas injection period of the gas storage reservoir, implement the "zoning regulation of pressure cone to drive water" operation of manually regulating the gas injection volume of each single well in the gas storage reservoir; during the gas production period of the gas storage reservoir, implement the "zoning and staged water control to increase production" operation. It can gradually alleviate the problem that the on-site injection and production of the injection and production wells in the bottom-water-containing gas storage reservoir cannot be carried out normally due to bottom water coning. The operation is convenient, the cost is low, the safety performance is high, it is environmentally friendly and reliable, and it can effectively alleviate the on-site injection and production operation of water coning in the bottom-water-containing gas storage reservoir. BRIEF DESCRIPTION OF THE DRAWINGS

[0021] In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the drawings required for use in the embodiments. Obviously, the drawings in the following description are only some embodiments of the present invention. For those of ordinary skill in the art, without creative efforts, other drawings can be obtained based on these drawings.

[0022] Figure 1 It is the step flow of a method for on-site injection and production operation to alleviate water coning in a bottom-water-containing gas storage reservoir of the present application;

[0023] Figure 2 It is the step flow during the gas injection period of the gas storage reservoir in a method for on-site injection and production operation to alleviate water coning in a bottom-water-containing gas storage reservoir of the present application. DETAILED DESCRIPTION OF THE EMBODIMENTS

[0024] Next, the technical solutions in the embodiments of the present invention will be clearly and completely described in conjunction with the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are only a part of the embodiments of the present invention, rather than all the embodiments.

[0025] In the description of the present invention, it should be understood that the orientation or positional relationship indicated by the terms "upper", "lower", "front", "rear", "left", "right", "top", "bottom", "inner", "outer", etc. is based on the orientation or positional relationship shown in the accompanying drawings, and is only for the convenience of describing the present invention and simplifying the description, rather than indicating or implying that the device or element referred to must have a specific orientation, be constructed and operated in a specific orientation, and therefore should not be construed as a limitation to the present invention.

[0026] As Figure 1 described, this embodiment provides a field injection-production operation method for alleviating water coning in a bottom-water-containing gas storage reservoir, and the method includes: step S100 and step S200.

[0027] Step S100: During the gas injection period of the gas storage reservoir, implement a zonal control pressure cone water drive operation for manually regulating the single-well gas injection volume of the gas storage reservoir, change the general gas injection method in which all injection-production wells are opened simultaneously during the gas injection period of the gas storage reservoir, and implement differential gas injection pressure cone water drive gas injection.

[0028] Step S200: During the gas production period of the gas storage reservoir, implement a zonal and staged water control and production increase operation. Based on the historical data of multi-cycle injection-production operation of the gas storage reservoir, accurately count the cumulative injection-production gas volume ratio of single wells in the water flooded and invaded area where the bottom water cones in and the water-liquid ratio in the cumulative liquid production of single wells in the normal injection-production area, and clarify the plane injection-production imbalance area of the bottom-water-containing gas storage reservoir.

[0029] The purpose of the present invention is to provide a field injection-production operation method for alleviating water coning in a bottom-water-containing gas storage reservoir to solve the problems of water flooding after water coning in injection-production wells and water invasion in injection-production wells during the injection-production process due to strong activity of the bottom water in the field injection-production operation process of the bottom-water-containing gas storage reservoir. Aiming at the problem of "water control injection-production" in the field, a field injection-production operation method for a bottom-water-containing buried hill gas storage reservoir is invented. The main practices of injecting to support production and zonal control include: during the gas injection period of the gas storage reservoir, implement a "zonal control pressure cone water drive" operation for manually regulating the single-well gas injection volume of the gas storage reservoir; during the gas production period of the gas storage reservoir, implement a "zonal and staged water control and production increase" operation. Its characteristics are that it can gradually alleviate the problem that the injection-production wells in the bottom-water-containing gas storage reservoir cannot operate normally due to bottom water coning, is convenient to operate, has low cost, high safety performance, is environmentally friendly and reliable, and can effectively alleviate the field injection-production operation of water coning in the bottom-water-containing gas storage reservoir.

[0030] Secondly, as Figure 2 in this embodiment, in step S100, the implementation of differential gas injection pressure cone water drive gas injection includes:

[0031] Step S110: Temporarily shut down the gas injection and production wells in the gas storage reservoir that are adjacent to the flooded wells and have good physical properties and relatively high free gas intake volume.

[0032] Step S120: For the flooded wells in the gas storage reservoir, inject gas pressure coning through the ground compressor in the gas gathering and injection station of the gas storage reservoir to achieve pressure coning to drive water and restore the gas injection volume of the flooded wells.

[0033] Secondly, in step S100 of this embodiment, when implementing differential injection pressure coning to drive water and inject gas, it further includes:

[0034] Step S130: Install a wellhead gas injection throttle valve on the gas injection pipeline of the production tree of the gas injection and production wells in the gas storage reservoir that have not been flooded and have a relatively high gas injection volume. Manually control the opening of the wellhead gas injection throttle valve to implement differential zoning regulation injection for flooded wells, water invaded wells, and normal wells, so as to achieve effective pressure coning for flooded and water invaded wells and optimize the gas injection process flow.

[0035] Among them, during the gas injection period of the gas storage reservoir, the method of zoning regulation pressure coning to drive water is adopted to adjust the single well gas injection volume of the artificial regulation of the gas storage reservoir. Different from the traditional gas injection method of opening wells simultaneously, by implementing differential injection pressure coning to drive water and inject gas. Temporarily shut down the gas injection and production wells in the gas storage reservoir that are adjacent to the flooded wells and have excellent physical properties and relatively high free gas intake volume, and use the ground compressor to inject gas pressure coning to drive the flooded wells and restore their gas injection volume. During the gas production period of the gas storage reservoir, a zoned and staged water control and production increase operation mode is adopted. According to the multi-cycle injection and production operation historical data of the gas storage reservoir, accurately count the injection and production gas volume ratio of single wells in the bottom water coning flooded and water invaded areas and the water-liquid ratio in the liquid production volume carried by gas production of single wells in the normal injection and production areas, and clarify the plane injection and production imbalance area of the gas storage reservoir with bottom water.

[0036] During the differential injection pressure coning process, since each gas injection and production well in the gas storage reservoir can only perform free gas intake and cannot manually control the single well gas injection volume, it is difficult to achieve effective pressure coning for a single well. Therefore, it is necessary to optimize the gas injection process flow. Specifically, a wellhead gas injection throttle valve is installed on the gas injection pipeline of the production tree of the gas injection and production wells in the gas storage reservoir that have not been flooded and have a relatively high gas injection volume, and the opening of the throttle valve is manually controlled to implement differential regulation for flooded wells, water invaded wells, and the normal injection and production area, so as to achieve effective pressure coning for flooded and water invaded wells.

[0037] In step S200 of this embodiment, when accurately counting the cumulative injection and production gas volume ratio of single wells in the bottom water coning flooded and water invaded areas and the water-liquid ratio in the cumulative liquid production volume carried by gas production of single wells in the normal injection and production areas based on the multi-cycle injection and production operation historical data of the gas storage reservoir to clarify the plane injection and production imbalance area of the gas storage reservoir with bottom water, it includes:

[0038] Based on the multi-cycle injection and production operation historical data of the gas storage reservoir, accurately calculate the upper limit index of the liquid-carrying volume per ten thousand cubic meters of gas at the moment of single well flooding in the gas storage reservoir with bottom water.

[0039] The upper limit index is based on the principle of achieving plane injection-production rebalance in a bottom-water-containing gas storage reservoir and ensuring that the liquid-carrying capacity per 10,000 cubic meters of gas in a single well is less than the upper limit index of the liquid-carrying capacity per 10,000 cubic meters of gas at the moment of single-well water flooding. According to the differences in the original gas-liquid interface of the reservoir and the water-avoiding heights of the wellbores of each injection-production well, gentle and stable gas production is mainly adopted for the injection-production wells in the water invasion area with bottom-water coning, while active production increase and peak shaving gas production are implemented for the single wells in the normal injection-production area.

[0040] Gentle and stable gas production as the main method and active production increase and peak shaving gas production are operation strategies for different injection-production areas. Gentle and stable gas production is mainly for the injection-production wells in the water invasion area with bottom-water coning ， To maintain the water-avoiding height of its wellbore, prevent bottom-water coning, and achieve stable gas production operation mode. While active production increase and peak shaving gas production is for the single wells in the normal injection-production area without bottom-water coning water invasion, which is a gas production operation mode adopted to increase the peak shaving and gas supply guarantee volume during the gas production period of the gas storage reservoir.

[0041] In this embodiment, the multi-cycle injection-production operation historical data of the gas storage reservoir includes: the liquid-carrying capacity per 10,000 cubic meters of gas for each single well, the dynamically monitored flowing pressure and static pressure values, the gas-liquid interface parameters, and the well stream component analysis data.

[0042] In this embodiment, in the above step S200, based on the multi-cycle injection-production operation historical data of the gas storage reservoir, accurately statistics the cumulative injection-production gas volume ratio of the single wells in the water flooded and invaded area with bottom-water coning and the single wells in the normal injection-production area, and the water-liquid ratio in the cumulative liquid production with gas production per single well, to clarify the plane injection-production imbalance area of the bottom-water-containing gas storage reservoir, further including:

[0043] Based on the liquid-carrying capacity per 10,000 cubic meters of gas for each single well, the dynamically monitored flowing pressure and static pressure values, the gas-liquid interface parameters, and the well stream component analysis data, comprehensively compare and analyze the multi-cycle on-site injection-production operation data of the bottom-water-containing gas storage reservoir, and conduct numerical simulation studies on the collected on-site data at different stages during the gas injection period and gas production period respectively, to understand the correlation between the variation law of the gas-liquid interface at different stages and the injection-production gas volume, providing technical reference for the next efficient on-site injection-production operation of the bottom-water-containing gas storage reservoir.

[0044] Among them, in order to accurately statistics the upper limit index of the liquid-carrying capacity per 10,000 cubic meters of gas at the moment of bottom-water coning, based on the multi-cycle injection-production operation historical data of the gas storage reservoir, calculate the upper limit index of the liquid-carrying capacity per 10,000 cubic meters of gas at the moment of single-well water flooding in the bottom-water-containing gas storage reservoir. According to the principle of achieving plane injection-production rebalance in the bottom-water-containing gas storage reservoir and ensuring that the liquid-carrying capacity per 10,000 cubic meters of gas in a single well is less than the upper limit index of the liquid-carrying capacity per 10,000 cubic meters of gas at the moment of single-well water flooding, and according to the differences in the original gas-liquid interface of the reservoir and the water-avoiding heights of the wellbores of each injection-production well, gentle and stable gas production is mainly adopted for the injection-production wells in the water invasion area with bottom-water coning, while active production increase and peak shaving gas production are implemented for the single wells in the normal injection-production area.

[0045] During the on-site gas production operation, based on production operation data such as the liquid-carrying volume per 10,000 cubic meters of gas in each single well, dynamic monitoring of flowing pressure and static pressure, gas-liquid interface, and well stream component analysis, the gas production operation of each single well is adjusted comprehensively and timely to suppress the point coning of the bottom water single well on the plane. To improve efficiency, comprehensive comparative analysis is carried out on the multi-cycle on-site injection and production operation data of the gas storage reservoir with bottom water, and numerical simulation research is conducted. Different stages of the injection period and the production period are studied respectively to determine the correlation between the change law of the gas-liquid interface and the injection and production gas volumes, providing technical reference for the next efficient on-site injection and production operation.

[0046] In this embodiment, the injection throttle valve is an angle throttle valve, and the type selection and size of the injection throttle valve are calculated according to the actual injection and production operation parameters of the gas storage reservoir.

[0047] The design parameters of the injection throttle valve mainly include: pressure, temperature, allowable pressure drop, flow rate, composition of the fluid, requirements for allowable leakage, and maximum noise level, etc. The type selection and size of the injection throttle valve should meet the on-site injection and production operation process conditions of the gas storage reservoir.

[0048] In this embodiment, the materials and pressure resistance levels of the valve body, valve cover, valve internals, and seals of the injection throttle valve conform to the working conditions at the installation location of the injection pipeline of the gas production tree in the injection and production well and the requirements of the on-site environment. The flow direction of the fluid should be clearly marked on the valve body. The opening degree of the throttle valve is displayed by the movement amount of the pointer attached to the valve stem or valve shaft.

[0049] Among them, in order to ensure the safety and reliability of the system, the selected injection throttle valve should conform to the working conditions at the installation location of the injection pipeline of the gas production tree in the injection and production well and have the ability to withstand pressure. Therefore, the type selection and size calculation of the injection throttle valve are carried out according to the actual injection and production operation parameters of the gas storage reservoir, and appropriate materials and pressure resistance levels are selected to meet the requirements of the on-site environment.

[0050] In summary, the on-site injection and production operation method for alleviating the water cone in the gas storage reservoir with bottom water provided by the embodiments of the present disclosure can solve the water cone problem in the gas storage reservoir with bottom water, improve the injection and production efficiency and system reliability through the methods of differential injection pressure coning to drive water injection and zoning and staged water control to increase production. At the same time, by optimizing the injection process flow and using a suitable injection throttle valve, more precise pressure coning to drive water and effective pressure control operations can be realized to ensure the normal operation of the gas storage reservoir.

[0051] The above is only a preferred specific embodiment of the present invention, but the protection scope of the present invention is not limited thereto. Any person skilled in the art within the technical scope disclosed by the present invention, according to the technical solution and inventive concept of the present invention, makes equivalent substitutions or changes, and all should be covered within the protection scope of the present invention.

Claims

1. A method for on-site injection and production operation to alleviate water cone in a gas storage reservoir containing bottom water, characterized in that: The method comprises: During the gas injection period of the gas storage reservoir, the gas storage reservoir is manually controlled to control the gas injection volume of a single well in a zoned manner, and the pressure cone water drive operation is implemented to change the general gas injection method of opening all injection and production wells at the same time during the gas injection period of the gas storage reservoir, and implement differentiated gas injection pressure cone water drive gas injection; During the gas production period of the gas storage, water control and increased production operations are implemented in different areas and stages. Based on the historical data of multi-cycle injection and production operations of the gas storage, the cumulative injection and production ratio of single wells in the flooded area with bottom water coning and the single well in the normal injection and production area, as well as the water-to-liquid ratio in the cumulative liquid production of single wells with gas production are accurately counted to identify the areas of injection-production imbalance in the plane of the gas storage containing bottom water.

2. The on-site injection and production operation method for alleviating water cone in a gas storage reservoir containing bottom water according to claim 1, characterized in that: The implementation of differentiated gas injection pressure cone drive water gas injection includes: Temporarily shut down the gas storage injection and production wells with good physical properties and relatively high free gas intake volume adjacent to the flooded wells in the gas storage; For the flooded wells in the gas storage reservoir, the ground compressor in the gas storage reservoir injection station is used to inject gas into the pressure cone to achieve the pressure cone drive water and restore the gas injection volume of the flooded wells.

3. The on-site injection and production operation method for alleviating water cone in a gas storage reservoir containing bottom water according to claim 2, characterized in that: The implementation of differentiated gas injection pressure cone drive water gas injection also includes: For the gas storage injection and production wells that have not been flooded and have a high gas injection volume, a wellhead gas injection throttle valve is installed on the gas injection pipeline of the gas tree. By manually controlling the opening of the wellhead gas injection throttle valve, differentiated zoning and regulated gas injection is implemented for water-flooded wells, water-invaded wells and normal wells to achieve effective cone pressure in water-flooded and water-invaded wells and optimize the gas injection process.

4. The on-site injection and production operation method for alleviating water cone in a gas storage reservoir containing bottom water according to claim 1, characterized in that: After obtaining the multi-cycle injection and production operation history data of the gas storage reservoir, it also includes: accurately calculating the upper limit index of the liquid volume carried by ten thousand cubic meters of gas at the time of flooding of a single well in the bottom water gas storage reservoir based on the multi-cycle injection and production operation history data of the gas storage reservoir.

5. The on-site injection and production operation method for alleviating water cone in a gas storage reservoir containing bottom water according to claim 4, characterized in that The upper limit index is based on the principle of plane injection and production rebalancing of gas storage reservoirs containing bottom water and the upper limit index of gas-liquid carrying volume per 10,000 cubic meters of a single well being less than the upper limit index of gas-liquid carrying volume per 10,000 cubic meters of a single well at the time of flooding. According to the difference in the original gas-liquid interface of the reservoir and the water avoidance height of the wellbore of each injection and production well, gentle and stable production gas production is mainly adopted for the injection and production wells in the water invasion area of ​​bottom water cone advance, and active production increase and peak regulation gas production is implemented for single wells in the normal injection and production area.

6. The on-site injection and production operation method for alleviating water cone in a gas storage reservoir containing bottom water according to claim 5, characterized in that The multi-cycle injection and production operation history data of the gas storage reservoir include: the volume of gas-liquid carried by each single well, the dynamic monitoring flow pressure and static pressure value, the gas-liquid interface parameters and the test data of the well flow components.

7. A method for on-site injection and production operation for alleviating water cone in a gas storage reservoir containing bottom water according to any one of claims 4 to 6, characterized in that: After obtaining the historical data of multi-cycle injection and production operations of the gas storage, it also includes: based on the gas-liquid volume per ten thousand cubic meters of each single well, the dynamic monitoring flow pressure and static pressure values, the gas-liquid interface parameters and the test data of the well flow components, a comprehensive comparative analysis of the multi-cycle field injection and production operation data of the bottom water gas storage, and numerical simulation research of the collected field data at different stages of the gas injection period and the gas production period, according to the correlation between the changing laws of the gas-liquid interface at different stages and the injection and production gas volume, reference data for efficient field injection and production operations of the bottom water gas storage is obtained.

8. The on-site injection and production operation method for alleviating water cone in a gas storage reservoir containing bottom water according to claim 3, characterized in that: The gas injection throttle valve is an angle throttle valve.

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