A method and related device for predicting variation of hydrogen sulfide content in gas storage and recovery
By establishing a mixed linear distribution model for hydrogen sulfide content using linear gradients, the problem of abundant and difficult hydrogen sulfide content prediction data in existing technologies is solved, achieving more accurate hydrogen sulfide content prediction and supporting the optimization of the safety and economy of gas storage facilities.
Patent Information
- Authority / Receiving Office
- CN · China
- Patent Type
- Applications(China)
- Current Assignee / Owner
- PETROCHINA CO LTD
- Filing Date
- 2024-11-29
- Publication Date
- 2026-05-29
AI Technical Summary
Existing methods for predicting hydrogen sulfide content require a large amount of basic data, making prediction difficult. Furthermore, it is challenging to accurately fit the gas storage model with multiple parameters that are mutually constrained, resulting in a high degree of ambiguity and making it difficult to effectively balance the safety and economy of gas storage facilities.
A mixed linear distribution model of hydrogen sulfide content is established using linear gradient. By obtaining the total amount of hydrogen sulfide in natural gas before the construction of the gas storage facility and the gas injection volume in the first cycle, the total amount and content of hydrogen sulfide after each cycle of gas injection are calculated, and the hydrogen sulfide content change curve is plotted, which reduces the need for basic data and improves the accuracy of prediction.
This enables more accurate prediction of the total amount and content of hydrogen sulfide in the produced gas for each cycle, improving prediction accuracy and providing technical support for subsequent optimization of gas storage injection and production operations, as well as drilling, production, and surface process design.
Smart Images
Figure CN122106550A_ABST
Abstract
Description
Technical Field
[0001] This invention belongs to the field of underground gas storage technology, and relates to a method and related device for predicting changes in hydrogen sulfide content during gas storage injection and extraction. Background Technology
[0002] Underground gas storage facilities generally refer to facilities that utilize existing underground storage spaces. During the off-season, natural gas is injected into the storage facility for storage, and during the peak season, it is rapidly extracted. This is a crucial means of ensuring national energy security and peak-shaving for downstream users. Currently, there are relatively few high-quality underground gas reservoirs suitable for conversion into storage facilities, and sulfur-bearing gas reservoirs are an important type for gas storage facility evaluation and construction. Gas produced from sulfur-bearing gas reservoirs contains acidic gases such as hydrogen sulfide, which can easily corrode pipelines and production equipment, affecting the operation of the storage facility. On the one hand, for safety reasons, drilling and surface process design should include appropriate purification processes and select high-standard sulfur-resistant equipment to ensure gas supply safety. On the other hand, for economic reasons, the purification process should be simplified as much as possible, and lower-standard sulfur-resistant equipment should be selected. Balancing the contradiction between the safety and economy of gas storage facilities is the core technical problem restricting the construction of gas storage facilities for acidic gas reservoirs.
[0003] Due to the influence of various factors such as the initial hydrogen sulfide content, the degree of production during reservoir construction, the injection and production volume, the injection and production rate, and the well spacing, it is quite difficult to predict the hydrogen sulfide content and optimize the operating parameters during the cyclic injection and production process of sulfur-bearing gas reservoirs. Existing technologies mainly rely on establishing numerical simulation models of hydrogen sulfide components to predict the variation law of hydrogen sulfide in multiple injection and production cycles. However, this method requires a large amount of basic data, has many historical fitting parameters, and the difficulty of accurately fitting the gas reservoir model with multiple parameters mutually constraining each other is high. The prediction results have a certain degree of ambiguity. Summary of the Invention
[0004] This invention provides a method and related apparatus for predicting changes in hydrogen sulfide content during gas storage injection and extraction, in order to solve the technical problems of existing hydrogen sulfide content prediction methods requiring a large amount of basic data and being difficult to predict.
[0005] To achieve the above objectives, the present invention employs the following technical solution: In a first aspect, the present invention provides a method for predicting changes in hydrogen sulfide content during gas storage injection and extraction, comprising the following steps: Obtain the total amount of hydrogen sulfide in the natural gas before the construction of the gas storage facility; Determine the injection and extraction volumes for each cycle of gas injection and extraction in the gas storage facility; The total amount of hydrogen sulfide in the natural gas before the gas storage facility was built and the amount of gas injected into the gas storage facility in the first cycle are used to calculate the total amount of hydrogen sulfide after the first cycle of gas injection into the gas storage facility. Based on the total amount of hydrogen sulfide after the first cycle of gas injection in the gas storage facility, a mixed linear distribution model of hydrogen sulfide content is established based on linear gradient, and the total amount of hydrogen sulfide and hydrogen sulfide content in the produced gas of the first cycle are predicted. Similarly, based on the injection and extraction volumes of the gas storage tank in each cycle, the average hydrogen sulfide content of the extracted gas in each cycle is calculated using a mixed linear distribution model of hydrogen sulfide content, and the hydrogen sulfide content variation curves for each cycle are plotted.
[0006] Furthermore, the step of obtaining the total amount of hydrogen sulfide in the natural gas before the construction of the gas storage facility specifically includes: The hydrogen sulfide content in the natural gas before the construction of the gas storage facility was determined through natural gas component testing. The total amount of hydrogen sulfide in the natural gas before the construction of the gas storage facility was then calculated based on the inventory levels. The specific calculation formula is as follows: S0=C0*G0 In the formula, S0 is the total amount of hydrogen sulfide in the natural gas before the construction of the gas storage facility; C0 is the hydrogen sulfide content in the natural gas before the construction of the gas storage facility; and G0 is the inventory before the construction of the storage facility.
[0007] Furthermore, the step of calculating the total amount of hydrogen sulfide in the natural gas before the gas storage facility was built and the amount of gas injected into the gas storage facility in the first cycle specifically includes: The hydrogen sulfide content (C) in the first cycle of gas injection into the gas storage facility was determined through natural gas component testing. 注1 ; Based on the hydrogen sulfide content C in the first cycle 注1 Injection volume G 注1 The total amount of hydrogen sulfide in the natural gas before storage construction is used to calculate the total amount of hydrogen sulfide after the first cycle of gas injection; the specific calculation formula is as follows: S1=S0+C 注1 * G 注1 In the formula, S1 is the total amount of hydrogen sulfide after the first cycle of gas injection in the gas storage facility; S0 is the total amount of hydrogen sulfide in the natural gas before the construction of the gas storage facility.
[0008] Furthermore, the step of establishing a mixed linear distribution model of hydrogen sulfide content based on a linear gradient after the first cycle of gas injection in the gas storage facility specifically includes: Based on the total hydrogen sulfide content S1 in the first cycle, a mixed linear distribution model of hydrogen sulfide content equal to S1 is established according to a linear gradient, and the hydrogen sulfide content T1 of the outermost virtual point is determined; the formula for calculating the hydrogen sulfide content T1 of the virtual point is: T1=S1 / (G0+G 注1 )*2 In the formula, S0 represents the total amount of hydrogen sulfide in the natural gas before the gas storage facility is built; G0 represents the inventory level before the facility is built; G 注1 This refers to the gas injection volume for the first cycle of the gas storage facility.
[0009] Furthermore, the step of calculating the average hydrogen sulfide content in the extracted gas for each cycle based on the injection and extraction volumes of the gas storage facility using a mixed linear distribution model of hydrogen sulfide content includes the following specific calculation formulas: S 采i = C 采i * G 采i S i =S i-1 - S 采i-1 T i = S i / (G i-1 +G 注i )*2 C 采i = G 采i * T i / (G i-1 +G 注i ) In the formula, S 采i G represents the total amount of hydrogen sulfide in the produced gas during the i-th cycle; 采i C represents the gas extraction volume for the i-th cycle; 采i S represents the hydrogen sulfide content in the produced gas during the i-th cycle; i S represents the total amount of hydrogen sulfide before the i-th cycle of gas injection in the gas storage facility; 采i-1 T represents the total amount of hydrogen sulfide in the produced gas during the (i-1)th cycle. i G represents the hydrogen sulfide content at the virtual point of the i-th period; i-1 G represents the inventory level after gas injection and production in the (i-1)th cycle; 注i Let be the gas injection volume for the i-th cycle.
[0010] Furthermore, it also includes: verifying the calculated results with the measured data of hydrogen sulfide in the produced gas of each cycle; if the error is within the preset range, the method is considered to be suitable for the analyzed data; otherwise, the data is reviewed or other methods are selected.
[0011] Furthermore, the preset range of the error is no greater than 10%.
[0012] Secondly, the present invention provides a system for predicting changes in hydrogen sulfide content during gas storage injection and extraction, comprising: The initial quantity acquisition module is used to obtain the total amount of hydrogen sulfide in the natural gas before the gas storage facility is built; The gas injection and extraction calculation module is used to determine the gas injection and extraction volume for each cycle of gas storage. The total amount calculation module is used to calculate the total amount of hydrogen sulfide in the natural gas before the gas storage facility is built and the amount of gas injected in the first cycle of the gas storage facility. The modeling module is used to establish a mixed linear distribution model of hydrogen sulfide content based on the total amount of hydrogen sulfide after the first cycle of gas injection in the gas storage facility, and to predict the total amount of hydrogen sulfide and hydrogen sulfide content in the produced gas during the first cycle. The prediction module is used to calculate the average hydrogen sulfide content of the extracted gas in each cycle based on the injection and extraction volumes of the gas storage facility, using a mixed linear distribution model of hydrogen sulfide content, and to plot the hydrogen sulfide content variation curve for each cycle.
[0013] Thirdly, the present invention provides a computer device including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the steps of the method described above.
[0014] Fourthly, the present invention provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the steps of the method described above.
[0015] Compared with the prior art, the present invention has the following beneficial effects: This invention discloses a method and related apparatus for predicting the changes in hydrogen sulfide content during gas storage and production. First, based on the total amount of hydrogen sulfide in the natural gas before the gas storage facility is built and the injection volume during the first cycle, the total amount of hydrogen sulfide after the first cycle of gas injection is determined. Then, a mixed linear distribution model of hydrogen sulfide content is established based on a linear gradient to predict the total amount and content of hydrogen sulfide in the produced gas during the first cycle. This process is repeated to calculate the average hydrogen sulfide content in the produced gas for each cycle using the mixed linear distribution model, and to plot the hydrogen sulfide content change curves for each cycle. This method requires less basic data and can more accurately predict the total amount and content of hydrogen sulfide in the produced gas for each cycle, thus improving the accuracy of hydrogen sulfide content prediction. It provides technical support for subsequent optimization of injection and production operations in sulfur-bearing gas reservoirs, as well as for drilling and production, surface process design optimization, and gas storage facility construction and operation. Attached Figure Description
[0016] To more clearly illustrate the technical solutions of the embodiments of the present invention, the accompanying drawings used in the embodiments will be briefly introduced below. It should be understood that the following drawings only show some embodiments of the present invention and should not be regarded as a limitation on the scope. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.
[0017] Figure 1 This is a flowchart of the method of the present invention; Figure 2 This is a schematic diagram of the system of the present invention; Figure 3The initial total amount of hydrogen sulfide in the gas reservoir according to an embodiment of the present invention; Figure 4 This refers to the total amount of residual hydrogen sulfide in the gas reservoir according to an embodiment of the present invention. Figure 5 This is a linear distribution model of hydrogen sulfide mixture in an embodiment of the present invention; Figure 6 This invention provides a method for predicting the hydrogen sulfide content in produced gas in an embodiment of the invention. Figure 7 This is a comparison between the calculation results and test results of the embodiments of the present invention; Figure 8 This is a schematic diagram of the computer device structure of the present invention. Detailed Implementation
[0018] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, 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. The components of the embodiments of the present invention described and shown in the accompanying drawings can generally be arranged and designed in various different configurations.
[0019] Therefore, the following detailed description of the embodiments of the invention provided in the accompanying drawings is not intended to limit the scope of the claimed invention, but merely to illustrate selected embodiments of the invention. All other embodiments obtained by those skilled in the art based on the embodiments of the invention without inventive effort are within the scope of protection of the invention.
[0020] It should be noted that similar labels and letters in the following figures indicate similar items. Therefore, once an item is defined in one figure, it does not need to be further defined and explained in subsequent figures.
[0021] In the description of the embodiments of the present invention, it should be noted that if terms such as "upper," "lower," "horizontal," or "inner" indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings, or the orientation or positional relationship commonly used when the product of the invention is in use, they are only for the convenience of describing the present 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, and therefore should not be construed as a limitation of the present invention. Furthermore, terms such as "first" and "second" are only used to distinguish descriptions and should not be construed as indicating or implying relative importance.
[0022] Furthermore, the use of the term "horizontal" does not imply that the component must be absolutely horizontal, but rather that it can be slightly tilted. For example, "horizontal" simply means that its direction is more horizontal than "vertical," and does not mean that the structure must be completely horizontal, but can be slightly tilted.
[0023] In the description of the embodiments of the present invention, it should also be noted that, unless otherwise explicitly specified and limited, the terms "set," "install," "connect," and "link" 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 or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; and they can refer to the internal connection of two components. Those skilled in the art can understand the specific meaning of the above terms in the present invention according to the specific circumstances.
[0024] The present invention will now be described in further detail with reference to the accompanying drawings: See Figure 1 This invention discloses a method for predicting changes in hydrogen sulfide content during gas storage injection and extraction, comprising the following steps: Step 1: Determine the hydrogen sulfide content C0 and inventory G0 in the natural gas before the gas storage facility is built, and calculate the total amount S0 of hydrogen sulfide in the gas storage facility. Figure 3 As shown. The specific calculation formula is: S0=C0*G0 The hydrogen sulfide content was obtained through natural gas component testing.
[0025] Step 2: Determine the gas injection volume G for each gas injection and extraction cycle in the gas storage facility. 注1 G 注2 G 注3 G 注4 ...G 注n Gas production volume G 采1 G 采2 G 采3 G 采4 ...G 采n .
[0026] Step 3: Determine the hydrogen sulfide content (C) in the gas injected into the storage facility during the first cycle through natural gas component testing. 注1 .
[0027] Based on the injection volume and its hydrogen sulfide content, determine the total amount of hydrogen sulfide after the first cycle of gas injection in the gas storage facility, such as... Figure 4 As shown, the specific calculation formula is as follows: S1=S0+C 注1 * G 注1 Step 4: Based on the total hydrogen sulfide content S1 in the first cycle, establish a mixed linear distribution model of hydrogen sulfide content equal to S1 according to the linear gradient, and determine the hydrogen sulfide content T1 of the outermost virtual point, such as... Figure 5 As shown. The specific formula for calculating T1 is: T1=S1 / (G0+G 注1 )*2 Step 5: Based on the produced gas volume of the first cycle, calculate the total hydrogen sulfide content S in the produced gas using the mixed linear distribution model of hydrogen sulfide content from Step 4. 采1 and component content C 采1 ,like Figure 6 As shown.
[0028] C 采1 = G 采1 * T1 / (G0+G 注1 ) S 采1 = C 采1 * G 采1 Step 6: Following this pattern, iterate through each cycle based on the gas injection and production volume, calculate the average hydrogen sulfide content in the produced gas for each cycle, and plot the hydrogen sulfide content variation curve for each cycle.
[0029] S 采i = C 采i * G 采i S i =S i-1 - S 采i-1 T i = S i / (G i-1 +G 注i )*2 C 采i = G 采i * T i / (G i-1 +G 注i ) Step 7: Verify the calculated results against the measured hydrogen sulfide data of the produced gas from each cycle. If the error is within 10%, the method is considered suitable for the analyzed data. Otherwise, verify the data or select another method.
[0030] See Figure 2 This invention discloses a system for predicting changes in hydrogen sulfide content during gas storage injection and production, comprising an initial quantity acquisition module, an injection and production volume calculation module, a total quantity calculation module, a modeling module, and a prediction module.
[0031] It should be noted that the initial quantity acquisition module is used to obtain the total amount of hydrogen sulfide in the natural gas before the gas storage facility is built; the injection and production volume calculation module is used to determine the injection and production volumes for each cycle of the gas storage facility; the total quantity calculation module is used to calculate the total amount of hydrogen sulfide after the first cycle of gas injection in the gas storage facility based on the total amount of hydrogen sulfide in the natural gas before the gas storage facility is built and the injection volume of the first cycle; the modeling module is used to establish a mixed linear distribution model of hydrogen sulfide content based on linear gradient based on the total amount of hydrogen sulfide after the first cycle of gas injection in the gas storage facility, and predict the total amount and content of hydrogen sulfide in the produced gas of the first cycle; the prediction module is used to calculate the average hydrogen sulfide content of the produced gas in each cycle based on the injection and production volumes of the gas storage facility in each cycle, and plot the hydrogen sulfide content change curves for each cycle.
[0032] Example: The following will provide a detailed description of a rapid method for predicting changes in hydrogen sulfide content during gas storage injection and extraction, provided by the present invention, through specific embodiments.
[0033] Step 1: Determine the hydrogen sulfide content C0 and inventory G0 in the natural gas before the gas storage facility is built, and calculate the total amount S0 of hydrogen sulfide in the gas storage facility.
[0034] S0=C0*G0=400 The hydrogen sulfide content was determined by natural gas component testing.
[0035] Step 2: Determine the gas injection volume G for each gas injection and extraction cycle in the gas storage facility. 注1 G 注2 G 注3 G 注4 ...G 注n Gas production volume G 采1 G 采2 G 采3 G 采4 ...G 采n As shown in Table 1 below: Table 1. Statistics and Plans of Gas Injection and Production Volume for Each Cycle
[0036] Step 3: Determine the hydrogen sulfide content (C) in the gas injected into the storage facility during the first cycle through natural gas component testing. 注1 .
[0037] Based on the injection volume and the hydrogen sulfide content, the total amount of hydrogen sulfide after the first cycle of gas injection in the gas storage facility is determined as S1 = S0 + C. 注1 * G 注1 .
[0038] Step 4: Based on the total amount of hydrogen sulfide S1 in the first cycle, establish a mixed linear distribution model of hydrogen sulfide content with the same amount as S1 according to the linear gradient, and determine the hydrogen sulfide content T1 of the outermost virtual point.
[0039] T1=S1 / (G0+G 注1 )*2 Step 5: Based on the produced gas volume of the first cycle, calculate the total hydrogen sulfide content S in the produced gas using the mixed linear distribution model of hydrogen sulfide content from Step 4. 采1 and component content C 采1 .
[0040] C 采1 = G 采1 * T1 / (G0+G 注1 ) S 采1 = C 采1 * G 采1 Step Six: Following this pattern, iterate through the gas injection and production volumes for each cycle to calculate the average hydrogen sulfide content in the produced gas for each cycle. See Table 2 below for the specific results.
[0041] S 采i = C 采i * G 采i S i =S i-1 - S 采i-1 T i = S i / (G i-1 +G 注i )*2 C 采i = G 采i * T i / (G i-1 +G 注i ) Table 2 Calculation of Average Hydrogen Sulfide Content for Each Period
[0042] Step Seven: See Figure 7 The calculated results were verified based on the measured hydrogen sulfide data of the produced gas in each cycle. Hydrogen sulfide content variation curves for each cycle were plotted. It was predicted that the hydrogen sulfide content in cycle 12 would be below 6 mg / m³. 3 The results are in good agreement with the numerical simulation results and can be used to monitor changes in hydrogen sulfide content in gas storage facilities.
[0043] In one embodiment of the invention, see [link to embodiment]. Figure 8A computer device is provided, comprising a processor and a memory. The memory stores a computer program, which includes program instructions. The processor executes the program instructions stored in the computer storage medium. The processor may be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. It is the computing and control core of the terminal, suitable for implementing one or more instructions, specifically suitable for loading and executing one or more instructions in the computer storage medium to achieve a corresponding method flow or corresponding function. The processor described in this embodiment can be used in the operation of a method for predicting changes in hydrogen sulfide content during gas storage tank injection and extraction.
[0044] This invention also provides a storage medium, specifically a computer-readable storage medium (Memory), which is a memory device in a computer device used to store programs and data. It is understood that the computer-readable storage medium here can include both the built-in storage medium in the computer device and extended storage media supported by the computer device. The computer-readable storage medium provides storage space that stores the terminal's operating system. Furthermore, this storage space also stores one or more instructions suitable for loading and execution by a processor. These instructions can be one or more computer programs (including program code). It should be noted that the computer-readable storage medium here can be high-speed RAM or non-volatile memory, such as at least one disk storage device. The processor can load and execute one or more instructions stored in the computer-readable storage medium to implement the corresponding steps of the method for predicting changes in hydrogen sulfide content in gas storage tanks described in the above embodiments.
[0045] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.
[0046] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.
[0047] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.
[0048] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.
[0049] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and not to limit it. Although the present invention has been described in detail with reference to the above embodiments, those skilled in the art should understand that modifications or equivalent substitutions can still be made to the specific implementation of the present invention. Any modifications or equivalent substitutions that do not depart from the spirit and scope of the present invention should be covered within the scope of protection of the claims of the present invention.
Claims
1. A method for predicting changes in hydrogen sulfide content during gas storage injection and extraction, characterized in that, Includes the following steps: Obtain the total amount of hydrogen sulfide in the natural gas before the construction of the gas storage facility; Determine the injection and extraction volumes for each cycle of gas injection and extraction in the gas storage facility; The total amount of hydrogen sulfide in the natural gas before the gas storage facility was built and the amount of gas injected into the gas storage facility in the first cycle are used to calculate the total amount of hydrogen sulfide after the first cycle of gas injection into the gas storage facility. Based on the total amount of hydrogen sulfide after the first cycle of gas injection in the gas storage facility, a mixed linear distribution model of hydrogen sulfide content is established based on linear gradient, and the total amount of hydrogen sulfide and hydrogen sulfide content in the produced gas of the first cycle are predicted. Similarly, based on the injection and extraction volumes of the gas storage tank in each cycle, the average hydrogen sulfide content of the extracted gas in each cycle is calculated using a mixed linear distribution model of hydrogen sulfide content, and the hydrogen sulfide content variation curves for each cycle are plotted.
2. The method for predicting changes in hydrogen sulfide content during gas storage injection and extraction according to claim 1, characterized in that, The steps for obtaining the total amount of hydrogen sulfide in the natural gas before the construction of the gas storage facility specifically include: The hydrogen sulfide content in the natural gas before the construction of the gas storage facility was determined through natural gas component testing. The total amount of hydrogen sulfide in the natural gas before the construction of the storage facility was then calculated based on the inventory levels. The specific calculation formula is as follows: S0=C0*G0 In the formula, S0 is the total amount of hydrogen sulfide in the natural gas before the construction of the gas storage facility; C0 is the hydrogen sulfide content in the natural gas before the construction of the gas storage facility; and G0 is the inventory before the construction of the storage facility.
3. The method for predicting changes in hydrogen sulfide content during gas storage injection and extraction according to claim 1, characterized in that, The step of calculating the total amount of hydrogen sulfide in the natural gas before the gas storage facility is built and the amount of gas injected in the first cycle of the gas storage facility specifically includes: The hydrogen sulfide content (C) in the first cycle of gas injection into the gas storage facility was determined through natural gas component testing. 注1 ; Based on the hydrogen sulfide content C in the first cycle 注1 Injection volume G 注1 The total amount of hydrogen sulfide in the natural gas before storage construction is used to calculate the total amount of hydrogen sulfide after the first cycle of gas injection; the specific calculation formula is as follows: S1=S0+C 注1 * G 注1 In the formula, S1 is the total amount of hydrogen sulfide after the first cycle of gas injection in the gas storage facility; S0 is the total amount of hydrogen sulfide in the natural gas before the construction of the gas storage facility.
4. The method for predicting changes in hydrogen sulfide content during gas storage injection and extraction according to claim 1, characterized in that, The step of establishing a mixed linear distribution model of hydrogen sulfide content based on a linear gradient after the first cycle of gas injection into the gas storage facility specifically includes: Based on the total hydrogen sulfide content S1 in the first cycle, a mixed linear distribution model of hydrogen sulfide content equal to S1 is established according to a linear gradient, and the hydrogen sulfide content T1 of the outermost virtual point is determined; the formula for calculating the hydrogen sulfide content T1 of the virtual point is: T1=S1 / (G0+G 注1 )*2 In the formula, S0 represents the total amount of hydrogen sulfide in the natural gas before the gas storage facility is built; G0 represents the inventory level before the facility is built; G 注1 This refers to the gas injection volume for the first cycle of the gas storage facility.
5. The method for predicting changes in hydrogen sulfide content during gas storage injection and extraction according to claim 1, characterized in that, The step of calculating the average hydrogen sulfide content in the extracted gas for each cycle based on the injection and extraction volumes of the gas storage facility using a mixed linear distribution model of hydrogen sulfide content includes the following specific calculation formulas: S 采i = C 采i * G 采i S i =S i-1 - S 采i-1 T i = S i / (G i-1 +G 注i )*2 C 采i = G 采i * T i / (G i-1 +G 注i ) In the formula, S 采i G represents the total amount of hydrogen sulfide in the produced gas during the i-th cycle; 采i C represents the gas extraction volume for the i-th cycle; 采i S represents the hydrogen sulfide content in the produced gas during the i-th cycle; i S represents the total amount of hydrogen sulfide before the i-th cycle of gas injection in the gas storage facility; 采i-1 T represents the total amount of hydrogen sulfide in the produced gas during the (i-1)th cycle. i G represents the hydrogen sulfide content at the virtual point of the i-th period; i-1 G represents the inventory level after gas injection and production in the (i-1)th cycle; 注i Let be the gas injection volume for the i-th cycle.
6. The method for predicting changes in hydrogen sulfide content during gas storage injection and extraction according to claim 1, characterized in that, Also includes: The method is verified by comparing the measured hydrogen sulfide data of the produced gas in each cycle with the calculated results. If the error is within the preset range, the method is considered to be suitable for the analyzed data; otherwise, the data is reviewed or other methods are selected.
7. The method for predicting changes in hydrogen sulfide content during gas storage injection and extraction according to claim 6, characterized in that, The preset range for the error is no more than 10%.
8. A system for predicting changes in hydrogen sulfide content during gas storage injection and extraction, characterized in that, include: The initial quantity acquisition module is used to obtain the total amount of hydrogen sulfide in the natural gas before the construction of the gas storage facility; The gas injection and extraction calculation module is used to determine the gas injection and extraction volume for each cycle of gas storage. The total amount calculation module is used to calculate the total amount of hydrogen sulfide in the natural gas before the gas storage facility is built and the amount of gas injected in the first cycle of the gas storage facility. The modeling module is used to establish a mixed linear distribution model of hydrogen sulfide content based on the total amount of hydrogen sulfide after the first cycle of gas injection in the gas storage facility, and to predict the total amount of hydrogen sulfide and hydrogen sulfide content in the produced gas during the first cycle. The prediction module is used to calculate the average hydrogen sulfide content of the extracted gas in each cycle based on the injection and extraction volumes of the gas storage facility, using a mixed linear distribution model of hydrogen sulfide content, and to plot the hydrogen sulfide content variation curve for each cycle.
9. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the steps of the method as described in any one of claims 1-7.
10. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by a processor, it implements the steps of the method as described in any one of claims 1-7.