Natural gas pipeline operation reliability analysis method and device, medium and electronic equipment

Abstract

The invention relates to a natural gas pipeline operation reliability analysis method and device, a medium and electronic equipment, and relates to the technical field of natural gas pipeline safety, and the method comprises the steps that at least one target pipe section with pipeline defects in a natural gas pipeline is obtained; when the target pipe sections are easy-to-leak pipe sections and the existing pipeline defects are corresponding easy-to-leak defects, determining the corresponding target pipe sections as key pipe sections, and based on the easy-to-leak defects existing in the key pipe sections, determining risk coefficients of leakage of the key pipe sections; and on the basis of the total historical leakage times of the key pipe sections and the latest leakage times and the risk coefficient within the preset time before the current time, the leakage risk level of the key pipe sections is determined through a preset risk level calculation formula, and when the leakage risk level exceeds a preset risk level threshold value, the key pipe sections are determined as high-risk pipe sections. The method has the effect of improving the identification accuracy of the pipe section with the high leakage risk in the natural gas pipeline.

Description

Technical Field

[0001] The present application relates to the field of natural gas pipeline safety technology, and in particular to a natural gas pipeline operation reliability analysis method, device, medium and electronic equipment. Background Art

[0002] A natural gas pipeline refers to a pipeline that transports natural gas (including associated gas produced in oil fields) from the mining site or processing plant to the urban gas distribution center or industrial enterprise users. Natural gas pipelines are widely used in many fields such as urban gas, industrial gas, power generation and transportation. Natural gas pipeline operation reliability analysis refers to the evaluation of the operating status of the natural gas pipeline to determine whether there is a risk of natural gas leakage, and then determine the reliability of the natural gas pipeline operation. In the process of natural gas transportation by natural gas pipelines, explosion accidents in natural gas pipelines are often closely related to natural gas leakage. Therefore, in order to better prevent the occurrence of explosion accidents, it is often necessary to conduct reliability analysis of natural gas pipeline operation, so as to better identify the sections of the natural gas pipeline with higher risks of natural gas leakage, and take targeted protective measures.

[0003] At present, the usual method for conducting operational reliability analysis on natural gas pipelines is: after identifying the defects in the natural gas pipeline, the identified defects are analyzed through an artificial intelligence model, and the sections of the natural gas pipeline with higher leakage risks are predicted to achieve operational reliability analysis of the natural gas pipeline. Under this method, since the performance of the artificial intelligence model is easily affected by overfitting, the accuracy of identifying sections with higher leakage risks is poor. Summary of the invention

[0004] In order to improve the accuracy of identifying pipe sections with higher leakage risks in natural gas pipelines, the present application provides a natural gas pipeline operation reliability analysis method, device, medium and electronic equipment.

[0005] In a first aspect of the present application, a method for analyzing the operation reliability of a natural gas pipeline is provided, which specifically includes: Acquire at least one target pipe section of a pipeline defect existing in a natural gas pipeline, wherein the pipeline defect is a defect inducing natural gas leakage; Determine at least one leak-prone pipe section and a corresponding leak-prone defect from each pipe section of the natural gas pipeline, wherein the leak-prone pipe section is a pipe section of the natural gas pipeline where natural gas leakage is likely to occur, and the leak-prone defect is a defect in the leak-prone pipe section that is likely to induce natural gas leakage; When the target pipe section is a leak-prone pipe section and the existing pipeline defect is a corresponding leak-prone defect, the corresponding target pipe section is determined as a key pipe section, and based on the leak-prone defect existing in the key pipe section, a risk coefficient of leakage of the key pipe section is determined; Based on the total number of historical leakages of the key pipeline section, the number of recent leakages within a preset time before the current time and the risk coefficient, the leakage risk level of the key pipeline section is determined by a preset risk level calculation formula, and when the leakage risk level exceeds a preset risk level threshold, the key pipeline section is determined as a high-risk pipeline section.

[0006] By adopting the above technical solution, after obtaining the target pipe section in the natural gas pipeline, the pipe section in the natural gas pipeline that is prone to leakage and the defects that are prone to induce leakage are determined. If the target pipe section is a leaky pipe section that is prone to leakage and the pipeline defects existing in this target pipe section are also corresponding leaky defects, it means that this target pipe section has the risk of natural gas leakage, then it is determined as a key pipe section, and according to the leaky defects existing in the key pipe section, the risk of leakage in the key pipe section is preliminarily analyzed to obtain the risk coefficient of leakage in the key pipe section. Further, combined with the historical leakage of this key pipe section and the recent leakage, the leakage risk level of this key pipe section is finally determined by the risk level calculation formula, that is, after optimizing the risk coefficient, the result of more accurately characterizing the risk of natural gas leakage. If the leakage risk level is greater than the risk level threshold, it means that the risk of natural gas leakage in this key pipe section is relatively high, then it is determined as a high-risk pipe section, thereby accurately identifying the pipe section with a higher leakage risk in the natural gas pipeline.

[0007] Optionally, the risk level calculation formula is: ; In the formula, R represents the leakage risk level of the key pipeline section, S represents the risk factor of leakage in the key pipeline section, Indicates the number of recent leaks in the key pipe section within the preset time before the current time. represents the total number of historical leakages in the key pipe section, T represents the duration corresponding to the preset time, Indicates the adjustment parameters, which adjust the impact of the recent leakage times on the current leakage risk level of the key pipeline section. Indicates the adjustment parameters, which adjust the impact of the total number of historical leakages on the current leakage risk level of the key pipeline section. A scaling parameter that represents the impact of the total number of historical leaks on the current leakage risk level of the key pipeline section.

[0008] By adopting the above technical solution, Indicates the frequency of natural gas leakage in key pipeline sections within a preset time. The function is to reduce the impact of the low frequency of recent leaks on the R calculation. Indicates the cumulative effect of leakage in key pipeline sections over a long period of time. The logarithm of can effectively avoid over-amplifying the impact of the total number of historical leakages on R, so that the final leakage risk level is more accurate. The role is to reduce When it is too low, it will have an impact on the calculation of R. As a result, the leakage risk level of the key pipe section calculated in the end is more accurate.

[0009] Optionally, the determining at least one leak-prone pipe section and a corresponding leak-prone defect from each pipe section of the natural gas pipeline specifically includes: Obtain the total number of historical natural gas leakages of each pipe section of the natural gas pipeline, and select the pipe section with the first number from each pipe section in descending order of the total number of historical leakages and determine it as a pipe section prone to leakage; Obtaining historical pipeline defects that induce natural gas leakage in each of the leaky pipe sections, counting the first occurrence times of each of the historical pipeline defects, and selecting the historical pipeline defect with the second occurrence times from each of the historical pipeline defects in descending order as the leaky defect of the corresponding leaky pipe section; The step of determining the risk factor of leakage of the key pipe section based on the leakage-prone defects in the key pipe section specifically includes: Determine a first weight of the key pipe section and a second weight of each existing leak-prone defect, wherein the first weight is the ratio of the total number of historical leakages of the key pipe section to the total number of historical leakages of all leak-prone pipe sections, and the second weight is the ratio of the first occurrence number of the leak-prone defect existing in the key pipe section to the sum of the first occurrence numbers of all corresponding leak-prone defects; The first weight product of the first weight and each corresponding second weight is calculated, and the first weight products are summed to obtain the risk coefficient of leakage of the key pipe section.

[0010] By adopting the above technical solution, the more the total number of historical leakages, the more likely the corresponding pipe section is to have natural gas leakage, and then the leaky pipe section is determined from the natural gas pipeline; the more the first occurrences, the more likely the historical pipeline defects corresponding to the leaky pipe section are to cause natural gas leakage, and then the leaky defects corresponding to the single leaky pipe section are determined. Further, the first weight product of the first weight and the second weight of each existing leaky defect is calculated. The larger the first weight product, the greater the possibility that the key pipe section will leak due to the corresponding leaky defect. Finally, the sum of the first weight products is calculated. The larger the sum result, the greater the possibility that the key pipe section as a whole will have natural gas leakage. The sum result is determined as the risk coefficient of leakage in this key pipe section, thereby accurately characterizing the risk of natural gas leakage in the key pipe section.

[0011] Optionally, the method further includes: Get the wind direction and wind speed at the current time; Based on the wind direction, determining the nearest target leakage monitoring point downstream of each high-risk pipe section; Based on the wind speed, determine the diffusion time of natural gas from each high-risk pipeline section to the corresponding target leakage monitoring point, and determine the maintenance order of the corresponding high-risk pipeline section according to the diffusion time. The longer the diffusion time, the earlier the corresponding maintenance order. Based on the maintenance sequence, each pipeline defect in the corresponding high-risk pipeline section is repaired in turn.

[0012] By adopting the above technical solution, the longer the diffusion time is, once the corresponding high-risk pipe section has a natural gas leak, it will take longer to be detected by the nearest target leak monitoring point, and the longer the natural gas leak is discovered, the higher the maintenance order of the corresponding high-risk pipe section needs to be, and the maintenance and repair will be given priority to avoid the problem of delayed detection when a natural gas leak occurs. Finally, according to the maintenance order, each pipeline defect in the corresponding high-risk pipe section is repaired one by one, which can not only eliminate the hidden dangers of natural gas leakage in the high-risk pipe section, but also avoid the problem of delayed detection when a natural gas leak occurs.

[0013] Optionally, the repairing each pipeline defect in the corresponding high-risk pipe section in sequence based on the repair sequence specifically includes: When the pipeline defect is pipeline outer wall corrosion, determining a target finite element model corresponding to the natural gas pipeline; Based on the target finite element model, determining the associated region of each existing region of the pipeline defect in the single high-risk pipe section, wherein the associated region is the region where the pipeline defect with increased stress value in each high-risk pipe section is located after the corresponding existing region is eliminated from stress concentration; Determine the post-repair impact value of the corresponding existing area according to the increased stress values ​​of each associated area corresponding to each existing area; Selecting the minimum post-maintenance impact value from the post-maintenance impact values ​​corresponding to the same high-risk pipe section, and determining the existence area corresponding to the minimum post-maintenance impact value as the area currently undergoing maintenance; The process of determining the associated region of each pipeline defect existing region in a single high-risk pipeline section based on the target finite element model is repeated until all the high-risk pipeline sections are overhauled.

[0014] By adopting the above technical solution, the associated area of ​​the existence area of ​​each pipeline defect in a single high-risk pipe section is determined. The associated area is the area where the stress value of the pipeline defect in each high-risk pipe section increases after the stress concentration of the corresponding existence area is eliminated, that is, after the corrosion of the existence area is repaired. Furthermore, the greater the impact value after overhaul, the greater the stress value of the area where the pipeline defect is located in the high-risk pipe section after the pipeline defect in the corresponding existence area is repaired, and the greater the risk of leakage. Finally, the minimum impact value after overhaul is selected from the various impact values ​​after overhaul corresponding to the same high-risk pipe section, and the existence area corresponding to this minimum impact value after overhaul is determined as the current priority overhaul area. Repeat the determination of the associated area of ​​the existence area of ​​each pipeline defect in a single high-risk pipe section based on the target finite element model until all high-risk pipe sections are overhauled, so that when each pipeline defect in a single high-risk pipe section is overhauled one by one, the leakage risk of each high-risk pipe section is less affected, avoiding the problem of pipeline leakage.

[0015] Optionally, determining the post-repair impact value of the corresponding existing area according to the increased stress values ​​of each associated area corresponding to each existing area specifically includes: Obtaining historical pipeline defects that induce natural gas leakage in a single high-risk pipeline section, counting the second occurrence times of each of the historical pipeline defects, and selecting the third historical pipeline defect from each of the historical pipeline defects in descending order of the second occurrence times to determine as the corresponding key leakage defect; Counting the historical occurrence areas of each of the key leakage defects in the corresponding high-risk pipe section, and counting the third occurrence times of each of the historical occurrence areas, and selecting the fourth number of historical occurrence areas from each of the historical occurrence areas in descending order of the third occurrence times to determine as the corresponding key leakage defect prone-to-occur area; Calculate the third weight of the key leakage defect of the single high-risk pipe section and the fourth weight of the corresponding prone area, the third weight is the ratio of the second occurrence number of the single key leakage defect to the sum of the second occurrence numbers of all key leakage defects, and the fourth weight is the ratio of the third occurrence number of the single prone area corresponding to the key leakage defect to the sum of the third occurrence numbers of all corresponding prone areas; The high-risk pipe section with the associated area is determined as a key focus pipe section, and based on the third weight and the corresponding fourth weight of the key focus pipe section, the weight coefficient of the associated area in the key focus pipe section is calculated, and the increased stress value of each associated area in the same key focus pipe section is multiplied by the corresponding weight coefficient and summed to obtain the corresponding initial post-inspection impact value; The weighted sum of the initial post-inspection impact values ​​is performed to obtain the post-inspection impact value of the corresponding existing area.

[0016] By adopting the above technical solution, the larger the second occurrence number, the more likely the corresponding historical pipeline defect is to cause natural gas leakage, thereby determining the key leakage defect; the larger the third occurrence number, the more likely the key leakage defect is to appear in the corresponding historical occurrence area, thereby determining the prone area. Furthermore, according to the third weight of the key focus pipe section and the corresponding fourth weight, the risk of natural gas leakage in the associated area of ​​the key focus pipe section is analyzed, and the corresponding weight coefficient is accurately determined, so that the accuracy of determining the post-maintenance impact value of the corresponding existing area is higher.

[0017] Optionally, the calculating the weight coefficient of the associated area in the key focus pipe segment based on the third weight and the corresponding fourth weight of the key focus pipe segment specifically includes: Calculate the second weight product of the third weight of the pipeline defect in the target associated area in the focused pipe section and the fourth weight of the corresponding target associated area, the pipeline defect in the target associated area is the key leakage defect corresponding to the focused pipe section, and the target associated area is the prone area corresponding to the focused pipe section; The second weight product is multiplied by 1 to obtain a weight coefficient of the corresponding target associated area, and the weight coefficient of the associated area other than the target associated area in the focused pipe segment is determined to be 1.

[0018] By adopting the above technical solution, the larger the second weight product is, the higher the possibility of leakage induced by pipeline defects in this target associated area. When the stress value of the target associated area increases, the risk of leakage is greatly affected, and the risk of leakage is high. Further, the second weight product is added with 1 to obtain the weight coefficient of the corresponding target associated area. At the same time, the weight coefficient of the associated area other than the target associated area in the key focus pipe section is determined to be 1, so as to more reasonably and accurately determine the weight coefficient of the increased stress value of the associated area, thereby improving the accuracy of the post-maintenance impact value of the existing area.

[0019] In a second aspect of the present application, a natural gas pipeline operation reliability analysis device is provided, which specifically includes: A pipe section acquisition module, used to acquire at least one target pipe section of a pipeline defect existing in a natural gas pipeline, wherein the pipeline defect is a defect that induces natural gas leakage; a defect determination module, used to determine at least one leak-prone pipe section and a corresponding leak-prone defect from each pipe section of the natural gas pipeline, wherein the leak-prone pipe section is a pipe section of the natural gas pipeline where natural gas leakage is likely to occur, and the leak-prone defect is a defect in the leak-prone pipe section that is likely to induce natural gas leakage; A coefficient calculation module, for determining the corresponding target pipe section as a key pipe section when the target pipe section is a leak-prone pipe section and the existing pipeline defect is a corresponding leak-prone defect, and determining a risk coefficient of leakage of the key pipe section based on the leak-prone defect existing in the key pipe section; The risk identification module is used to determine the leakage risk level of the key pipeline section based on the total number of historical leakages of the key pipeline section, the number of recent leakages within a preset time before the current time and the risk coefficient, through a preset risk level calculation formula, and when the leakage risk level exceeds a preset risk level threshold, the key pipeline section is determined as a high-risk pipeline section.

[0020] By adopting the above technical solution, the pipe section acquisition module acquires the target pipe section, the defect determination module determines at least one leak-prone pipe section and the corresponding leak-prone defect, and then the coefficient calculation module determines the risk coefficient of leakage of the key pipe section based on the leak-prone defects existing in the key pipe section after the target pipe section is determined as the key pipe section. Finally, the risk identification module determines the leakage risk level of the key pipe section through the risk level calculation formula, and determines the key pipe section as a high-risk pipe section when the leakage risk level exceeds the risk level threshold.

[0021] In a third aspect of the present application, a computer-readable storage medium is provided, in which a computer program is stored. When the computer program is loaded and executed by a processor, the method steps described in any one of the first aspects are performed.

[0022] In a fourth aspect of the present application, an electronic device is provided, specifically comprising: A processor, a memory, and a computer program stored in the memory and capable of running on the processor, wherein the processor is used to load and execute the computer program stored in the memory so that the electronic device performs the method as described in any one of the first aspects.

[0023] In summary, the present application includes at least one of the following beneficial technical effects: if the target pipe section is a leaky pipe section that is prone to leakage and the pipeline defect existing in this target pipe section is also a corresponding leaky defect, it means that this target pipe section has a risk of natural gas leakage, then it is determined as a key pipe section, and according to the leaky defects existing in the key pipe section, the risk of leakage in the key pipe section is preliminarily analyzed to obtain the risk coefficient of leakage in the key pipe section. Further, combined with the historical leakage of this key pipe section and the recent leakage, the leakage risk level of this key pipe section is finally determined through the risk level calculation formula, that is, after optimizing the risk coefficient, the result of more accurately characterizing the risk of natural gas leakage. If the leakage risk level is greater than the risk level threshold, it means that the risk of natural gas leakage in this key pipe section is relatively high, then it is determined as a high-risk pipe section, thereby realizing accurate identification of pipe sections with higher leakage risks in natural gas pipelines. BRIEF DESCRIPTION OF THE DRAWINGS

[0024] Figure 1 It is a flow chart of a method for analyzing the reliability of natural gas pipeline operation provided in an embodiment of the present application; Figure 2 It is a flow chart of another method for analyzing the reliability of natural gas pipeline operation provided by an embodiment of the present application; Figure 3 It is a structural schematic diagram of a natural gas pipeline operation reliability analysis device provided in an embodiment of the present application; Figure 4 It is a structural schematic diagram of another natural gas pipeline operation reliability analysis device provided in an embodiment of the present application.

[0025] Explanation of the accompanying drawings: 11. Pipe section acquisition module; 12. Defect determination module; 13. Coefficient calculation module; 14. Risk identification module; 15. Defect repair module. DETAILED DESCRIPTION

[0026] In order to enable those skilled in the art to better understand the technical solutions in this specification, the technical solutions in the embodiments of this specification will be clearly and completely described below in conjunction with the drawings in the embodiments of this specification. Obviously, the described embodiments are only part of the embodiments of this application, not all of the embodiments.

[0027] In the description of the embodiments of the present application, words such as "illustrative", "for example" or "for example" are used to indicate examples, illustrations or descriptions. Any embodiment or design described as "illustrative", "for example" or "for example" in the embodiments of the present application should not be interpreted as being more preferred or more advantageous than other embodiments or designs. Specifically, the use of words such as "illustrative", "for example" or "for example" is intended to present related concepts in a concrete way.

[0028] See also Figure 1 The embodiment of the present application discloses a flow chart of a method for analyzing the reliability of natural gas pipeline operation, which can be implemented by a computer program or run on a natural gas pipeline operation reliability analysis device based on the von Neumann system. The computer program can be integrated into an application or run as an independent tool application, specifically including: S101: Acquire at least one target pipe section with pipeline defects existing in a natural gas pipeline.

[0029] Specifically, a natural gas pipeline refers to a pipeline that transports natural gas (including associated gas produced in oil fields) from a mining site or a processing plant to a city gas distribution center or an industrial enterprise user. Natural gas pipelines are widely used in many fields such as urban gas, industrial gas, power generation, and transportation. In an embodiment of the present application, a natural gas pipeline refers to a pipeline that provides natural gas for the lives of urban residents. In other embodiments, it may also be a pipeline that provides natural gas for industrial production. Pipeline defects are defects that induce natural gas leakage. They may be corrosion on the inner and outer walls of the natural gas pipeline, or cracks that do not penetrate the inner and outer walls of the natural gas pipeline. Furthermore, the natural gas pipeline includes multiple pipe sections, which are usually divided according to specific geographical locations, functional requirements, or management boundaries. If there is a pipeline defect in a single pipe section, it is determined as a target pipe section.

[0030] In addition, the execution subject of the natural gas pipeline operation reliability analysis method disclosed in the embodiment of the present application is a server, which can be an independent physical server, or a server cluster or distributed system composed of multiple physical servers. The server and the pipeline robot are wirelessly connected through a wireless network so that the two can interact. Among them, the pipeline robot is an integrated mechatronic system that can automatically walk along the inside or outside of the natural gas pipeline, carry one or more sensors and operating machinery, and perform a series of pipeline operations under the automatic control of a computer, and can monitor and diagnose defects inside the natural gas pipeline.

[0031] Furthermore, a feasible way to monitor pipeline defects in natural gas pipelines is to detect pipeline defects in natural gas pipelines through pipeline robots with set inspection routes. Once pipeline defects are detected, the specific pipeline defects and the pipeline section information are sent to the server, and the target pipeline section with pipeline defects in the natural gas pipeline is finally determined. In other embodiments, pipeline defects on the outer wall of the natural gas pipeline can also be detected by pipeline drones.

[0032] S102: Determine at least one leak-prone pipe section and a corresponding leak-prone defect from each pipe section of the natural gas pipeline.

[0033] Specifically, the leak-prone pipe section is a pipe section of the natural gas pipeline that is prone to natural gas leakage, and the leak-prone defect is a defect in the leak-prone pipe section that is prone to induce natural gas leakage. A feasible implementation method is: retrieve the electronic archive record of natural gas leakage in the natural gas pipeline, and the electronic archive record includes the pipe section where the leakage occurs and the specific defect that induces the leakage. From this electronic archive record, the total number of historical leakages of natural gas leakage in each pipe section of the natural gas pipeline is counted. The more the total number of historical leakages, the more likely the corresponding pipe section is to have natural gas leakage. According to the order of the total number of historical leakages from large to small, the pipe section with the first number is selected from each pipe section and determined as the leak-prone pipe section. Further, then obtain the historical pipeline defects that induce natural gas leakage in the historical natural gas leakage event of a single leak-prone pipe section, count the first occurrence number of each historical pipeline defect, the more the first occurrence number, the more likely the historical pipeline defect corresponding to the leak-prone pipe section is to cause natural gas leakage, and then select the second number of historical pipeline defects from each historical pipeline defect to determine it as the leak-prone defect of the corresponding leak-prone pipe section, and each leak-prone pipe section corresponds to at least one leak-prone defect.

[0034] S103: When the target pipe section is a leak-prone pipe section and the existing pipeline defect is a corresponding leak-prone defect, the corresponding target pipe section is determined as a key pipe section, and based on the leak-prone defect existing in the key pipe section, a risk coefficient of leakage of the key pipe section is determined.

[0035] Specifically, after each leak-prone pipe section and the corresponding leak-prone defects are determined, if the target pipe section is a leak-prone pipe section, and the pipeline defect existing in this target pipe section is the leak-prone defect corresponding to this target pipe section, this target pipe section is determined as a key pipe section, and based on the leak-prone defects existing in this key pipe section, the risk coefficient of leakage in this key pipe section is determined. In an embodiment of the present application, a feasible determination method is: determine a first weight of this key pipe section and a second weight of each leak-prone defect that exists, wherein the first weight is the ratio of the total number of historical leakages of the key pipe section to the sum of the total number of historical leakages of all leak-prone pipe sections, and the second weight is the ratio of the first occurrence number of the leak-prone defects existing in the key pipe section to the sum of the first occurrence numbers of all corresponding leak-prone defects. Furthermore, the first weight product of the first weight and the second weight of each corresponding leak-prone defect (each pipeline defect existing in the key pipeline section) is calculated. The larger the first weight product is, the greater the possibility that the key pipeline section will leak due to the corresponding leak-prone defect is. Finally, the first weight products are summed up. The larger the sum result is, the greater the possibility of natural gas leakage in the key pipeline section as a whole. The sum result is determined as the risk coefficient for leakage in this key pipeline section. The larger the risk coefficient is, the greater the probability of leakage in the key pipeline section as a whole.

[0036] S104: Based on the total number of historical leakages of the key pipeline section, the number of recent leakages within a preset time before the current time and the risk coefficient, the leakage risk level of the key pipeline section is determined by a preset risk level calculation formula, and when the leakage risk level exceeds a preset risk level threshold, the key pipeline section is determined as a high-risk pipeline section.

[0037] Specifically, after the risk coefficient corresponding to the key pipeline section is determined, the number of recent leakages of this key pipeline section within a preset time before the current time is obtained from the electronic archive record. The preset time can be 1 month, and in other embodiments, it can also be 0.5 months. Further, the total number of historical leakages, the number of recent leakages and the risk coefficient of this key pipeline section are substituted into the preset risk level calculation formula to obtain the leakage risk level of this key pipeline section. The higher the leakage risk level, the higher the risk of natural gas leakage in the key pipeline section. The risk level calculation formula is: ; In the formula, R represents the leakage risk level of the key pipeline section, S represents the risk factor of leakage in the key pipeline section, Indicates the number of recent leaks in the key pipe section within the preset time before the current time. represents the total number of historical leakages in the key pipe section, T represents the duration corresponding to the preset time, Indicates the adjustment parameters, which adjust the impact of the recent leakage times on the current leakage risk level of the key pipeline section. Indicates the adjustment parameters, which adjust the impact of the total number of historical leakages on the current leakage risk level of the key pipeline section. The scaling parameter represents the impact of the total number of historical leakages on the current leakage risk level of the key pipeline section. It is used to scale the impact of the total number of historical leakages on R to avoid the nonlinear increase of R caused by the total number of historical leakages.

[0038] It should be noted that Indicates the frequency of natural gas leakage in key pipeline sections within a preset time. The function is to reduce the impact of the low frequency of recent leaks on the R calculation. Indicates the cumulative effect of leakage in key pipeline sections over a long period of time. The logarithm of can effectively avoid over-amplifying the impact of the total number of historical leakages on R, so that the final leakage risk level is more accurate. The role is to reduce When it is too low, it will have an impact on the calculation of R. As a result, the leakage risk level of the key pipe section calculated in the end is more accurate.

[0039] Furthermore, the leakage risk level of the key pipeline section is compared with the preset risk level threshold. If the leakage risk level is greater than the risk level threshold, it means that the risk of natural gas leakage in this key pipeline section is relatively high, and it is determined as a high-risk pipeline section, thereby achieving accurate identification of pipeline sections with higher leakage risks in the natural gas pipeline.

[0040] See also Figure 2 The present application embodiment discloses a flow chart of another method for analyzing the reliability of natural gas pipeline operation, which can be implemented by a computer program or run on a natural gas pipeline operation reliability analysis device based on the von Neumann system. The computer program can be integrated into an application or run as an independent tool application, specifically including: S201: Acquire at least one target pipe section with pipeline defects existing in a natural gas pipeline.

[0041] S202: Determine at least one leak-prone pipe section and a corresponding leak-prone defect from each pipe section of the natural gas pipeline.

[0042] S203: When the target pipe section is a leak-prone pipe section and the existing pipeline defect is a corresponding leak-prone defect, the corresponding target pipe section is determined as a key pipe section, and based on the leak-prone defect existing in the key pipe section, a risk coefficient of leakage of the key pipe section is determined.

[0043] S204: Based on the total number of historical leakages of the key pipeline section, the number of recent leakages within a preset time before the current time and the risk coefficient, the leakage risk level of the key pipeline section is determined by a preset risk level calculation formula, and when the leakage risk level exceeds a preset risk level threshold, the key pipeline section is determined as a high-risk pipeline section.

[0044] For details, please refer to steps S101-S104, which will not be described in detail here.

[0045] S205: Obtain wind direction and wind speed at the current time.

[0046] S206: Based on the wind direction, determine the nearest target leakage monitoring point downstream of each high-risk pipe segment.

[0047] S207: Based on the wind speed, determine the diffusion time of natural gas from each high-risk pipeline section to the corresponding target leakage monitoring point, and determine the maintenance order of the corresponding high-risk pipeline section according to the diffusion time. The longer the diffusion time, the earlier the corresponding maintenance order.

[0048] S208: Based on the maintenance sequence, each pipeline defect in the corresponding high-risk pipeline section is repaired in turn.

[0049] Specifically, the wind speed and wind direction at the current time are obtained through the wind speed and wind direction sensors preset in the area where the natural gas pipeline is located. Then, the location information of the leakage monitoring point is obtained through the GPS module of the preset leakage monitoring point near the natural gas pipeline, wherein the setting of the leakage monitoring point is to timely discover and deal with the leakage of the natural gas pipeline to ensure the safety and stability of the natural gas supply. According to the location information, the target leakage monitoring point closest to the downstream of a single high-risk pipe section in the wind direction is screened out from each leakage monitoring point. Further, according to the location information of a single high-risk pipe section and the corresponding target leakage monitoring point, the distance between the two is determined, and the distance is divided by the wind speed to determine the diffusion time of natural gas from this single high-risk pipe section to the corresponding target leakage monitoring point. The longer the diffusion time, once the corresponding high-risk pipe section has a natural gas leak, it will take a longer time to be detected by the nearest target leakage monitoring point, and the more untimely the natural gas leak is discovered, the higher the maintenance order of the corresponding high-risk pipe section needs to be, and the maintenance and maintenance are given priority to avoid the problem of untimely discovery when a natural gas leak occurs.

[0050] Further, in accordance with the maintenance order, the corresponding high-risk pipe sections are repaired in turn, that is, each pipeline defect in the corresponding high-risk pipe section is repaired one by one to eliminate the hidden danger of natural gas leakage in the high-risk pipe section. Among them, each pipeline defect in the high-risk pipe section is repaired, and a feasible implementation method is: when the pipeline defect is corrosion of the outer wall of the pipeline, the pipeline robot obtains the parameters of the pipeline wall thickness in the area where the pipeline defect is located, and based on the electronic design drawing of the natural gas pipeline, the length, material, normal wall thickness and pipe mouth diameter of the natural gas pipeline are obtained. The parameters are input into the finite element analysis software to create a corresponding three-dimensional geometric model, and the finite element mesh is divided, the analysis type and the solver options are set, and finally the target finite element model corresponding to the natural gas pipeline is obtained. This is the prior art and will not be repeated here. Among them, the finite element analysis software is ANSYS software, and in other embodiments, it can also be ABAQUS software. In addition, the finite element model (Finite Element Model, FEM) is a numerical calculation method that approximates the physical behavior of the entity by discretizing the continuous physical structure into a finite number of small parts, namely "elements". In the embodiment of the present application, the target finite element model refers to a finite element model established for the natural gas pipeline, which can be used to simulate and analyze the stress distribution in various areas of the natural gas pipeline.

[0051] Further, based on this target finite element model, the associated area of ​​each existing area of ​​the pipeline defect in a single high-risk pipe section is determined. The associated area is the area where the pipeline defect with increased stress value is located in each high-risk pipe section after the corresponding existing area is eliminated from stress concentration, that is, after the corrosion of the existing area is repaired. A feasible determination method is: through the finite element analysis software, the state of the existing area in a single high-risk pipe section in the target finite element analysis model is modified to a non-stress concentration area, and the adjusted finite element model is obtained. Then, through the adjusted finite element model, the area where the pipeline defect with increased stress value is located in each high-risk pipe section is determined and the increased stress value is obtained. Further, for the same high-risk pipe section, the increased stress values ​​of the associated area corresponding to each existing area in it are summed to obtain the corresponding maintenance impact value of the existing area. The larger the maintenance impact value, the greater the stress value of the area where the pipeline defect is located in the high-risk pipe section after the pipeline defect in the corresponding existing area is repaired, and the greater the risk of leakage. Therefore, the minimum maintenance impact value is selected from the various maintenance impact values ​​corresponding to the same high-risk pipe section, and the existing area corresponding to the minimum maintenance impact value is determined as the current priority maintenance area. By analogy, the target finite element model is repeatedly executed to determine the associated area of ​​each pipeline defect in a single high-risk pipeline section until all high-risk pipeline sections are overhauled. This ensures that when each pipeline defect in a single high-risk pipeline section is overhauled, the leakage risk of each high-risk pipeline section is less affected, thus avoiding pipeline leakage problems.

[0052] In other embodiments, according to the increased stress values ​​of each associated area corresponding to each existing area, the post-maintenance impact value of the corresponding existing area is determined, specifically including: obtaining the historical pipeline defects that induce natural gas leakage in a single high-risk pipe section and counting the second occurrence times of each historical pipeline defect, selecting the third number of historical pipeline defects from each historical pipeline defect in the order of the second occurrence times from large to small to determine as the key leakage defect, that is, the pipeline defect that is easy to induce leakage in the single high-risk pipe section. Further, counting the historical occurrence area of ​​each key leakage defect in the corresponding high-risk pipe section, counting the third occurrence times of each historical occurrence area, selecting the fourth number of historical occurrence areas from each historical occurrence area in the order of the third occurrence times from large to small to determine as the corresponding key leakage defect prone area, that is, the key leakage defect prone area.

[0053] Furthermore, the third weight of the key leakage defect of a single high-risk pipe section and the fourth weight of the corresponding prone area are calculated, the third weight being the ratio of the second occurrence number of a single key leakage defect to the sum of the second occurrence numbers of all key leakage defects, and the fourth weight being the ratio of the third occurrence number of a single prone area corresponding to the key leakage defect to the sum of the third occurrence numbers of all corresponding prone areas.

[0054] Further, the high-risk pipe section with associated areas is determined as the key focus pipe section, and the weight coefficient of the associated area in the key focus pipe section is calculated based on the third weight and the corresponding fourth weight of the key focus pipe section, specifically: the second weight product of the third weight of the pipeline defect in the target associated area in the key focus pipe section and the corresponding fourth weight of the target associated area is calculated, and the larger the second weight product is, the higher the possibility of leakage induced by the pipeline defect in the target associated area is. When the stress value of the target associated area increases, the risk of leakage is greater, and the risk of leakage is higher. Further, the second weight product is added by 1 to obtain the weight coefficient of the corresponding target associated area, and the weight coefficient of the associated area other than the target associated area in the key focus pipe section is determined to be 1. After the weight coefficients of each associated area in the key focus pipe section are determined, the increased stress values ​​of each associated area in the same key focus pipe section are multiplied by the corresponding weight coefficients and summed to obtain the initial post-inspection impact value of the corresponding key focus pipe section. Among them, the initial post-inspection impact value represents the degree of influence on the leakage risk of the key focus pipe section after the corresponding existing area is repaired and repaired. In addition, the pipeline defects in the target associated area are key leakage defects corresponding to the key focus pipe section, and the target associated area is therefore the prone area corresponding to the key focus pipe section.

[0055] Finally, a weighted sum is performed on each initial post-inspection impact value. Specifically, the corresponding weight assignment can be determined according to the leakage risk level of the high-risk pipe section corresponding to each initial post-inspection impact value. The higher the leakage risk level, the greater the impact of the increase in stress value on the leakage risk, and the greater the weight assignment, and then the corresponding post-inspection impact value of the existing area is obtained, thereby improving the accuracy of the post-inspection impact value to a certain extent.

[0056] The implementation principle of the natural gas pipeline operation reliability analysis method of the embodiment of the present application is: if the target pipe section is a leaky pipe section that is prone to leakage and the pipeline defect existing in this target pipe section is also a corresponding leaky defect, it means that this target pipe section has the risk of natural gas leakage, then it is determined as a key pipe section, and according to the leaky defects existing in the key pipe section, the risk of leakage in the key pipe section is preliminarily analyzed to obtain the risk coefficient of leakage in the key pipe section. Further, combined with the historical leakage of this key pipe section and the recent leakage, the leakage risk level of this key pipe section is finally determined through the risk level calculation formula, that is, after optimizing the risk coefficient, the result of more accurately characterizing the risk of natural gas leakage. If the leakage risk level is greater than the risk level threshold, it means that the risk of natural gas leakage in this key pipe section is relatively high, then it is determined as a high-risk pipe section, thereby accurately identifying the pipe section with a higher leakage risk in the natural gas pipeline.

[0057] The following is an embodiment of the device of the present application, which can be used to execute the embodiment of the method of the present application. For details not disclosed in the embodiment of the device of the present application, please refer to the embodiment of the method of the present application.

[0058] See also Figure 3 , is a schematic diagram of the structure of the natural gas pipeline operation reliability analysis device provided in the embodiment of the present application. The natural gas pipeline operation reliability analysis device can be implemented as all or part of the device through software, hardware or a combination of both. The device includes a pipe section acquisition module 11, a defect determination module 12, a coefficient calculation module 13 and a risk identification module 14.

[0059] The pipe section acquisition module 11 is used to acquire at least one target pipe section of a pipeline defect existing in a natural gas pipeline, where the pipeline defect is a defect that induces natural gas leakage; The defect determination module 12 is used to determine at least one leak-prone pipe section and a corresponding leak-prone defect from each pipe section of the natural gas pipeline, wherein the leak-prone pipe section is a pipe section of the natural gas pipeline where natural gas leakage is likely to occur, and the leak-prone defect is a defect in the leak-prone pipe section that is likely to induce natural gas leakage; The coefficient calculation module 13 is used to determine the corresponding target pipe section as a key pipe section when the target pipe section is a leak-prone pipe section and the existing pipeline defect is a corresponding leak-prone defect, and determine the risk coefficient of leakage of the key pipe section based on the leak-prone defect existing in the key pipe section; The risk identification module 14 is used to determine the leakage risk level of the key pipeline section based on the total number of historical leakages of the key pipeline section, the number of recent leakages within a preset time before the current time and the risk coefficient, through a preset risk level calculation formula, and when the leakage risk level exceeds a preset risk level threshold, the key pipeline section is determined as a high-risk pipeline section.

[0060] Optionally, the defect determination module 12 is specifically configured to: Obtain the total number of historical natural gas leaks in each section of the natural gas pipeline, and select the first section from each section in descending order of the total number of historical leaks and determine it as the section prone to leakage; The historical pipeline defects that induce natural gas leakage in each leak-prone pipe section are obtained, the first occurrence number of each historical pipeline defect is counted, and the historical pipeline defect with the second number is selected from each historical pipeline defect in descending order of the first occurrence number to determine it as the leak-prone defect of the corresponding leak-prone pipe section.

[0061] Optionally, the coefficient calculation module 13 is specifically used for: Determine the first weight of the key pipe section and the second weight of each existing leak-prone defect, the first weight being the ratio of the total number of historical leakages of the key pipe section to the total number of historical leakages of all leak-prone pipe sections, and the second weight being the ratio of the first occurrence number of the leak-prone defect existing in the key pipe section to the sum of the first occurrence numbers of all corresponding leak-prone defects; The first weight product of the first weight and each corresponding second weight is calculated, and the first weight products are summed to obtain the risk coefficient of leakage in the key pipe section.

[0062] Optional, such as Figure 4 As shown, the device also includes a defect repair module 15, which is specifically used to: Get the wind direction and wind speed at the current time; Based on wind direction, determine the nearest target leakage monitoring point downstream of each high-risk pipeline segment; Based on the wind speed, determine the diffusion time of natural gas from each high-risk pipeline section to the corresponding target leakage monitoring point, and determine the maintenance order of the corresponding high-risk pipeline section according to the diffusion time. The longer the diffusion time, the earlier the corresponding maintenance order. Based on the maintenance sequence, each pipeline defect in the corresponding high-risk pipeline section is repaired in turn.

[0063] Optionally, the defect repair module 15 is specifically used for: When the pipeline defect is pipeline outer wall corrosion, determining a target finite element model corresponding to the natural gas pipeline; Based on the target finite element model, determining the associated region of each existing region of the pipeline defect in the single high-risk pipe section, the associated region being the region where the pipeline defect with increased stress value in each high-risk pipe section is located after the corresponding existing region is eliminated from stress concentration; Determine the post-repair impact value of the corresponding existing area according to the increased stress values ​​of each associated area corresponding to each existing area; Select the minimum post-maintenance impact value from the post-maintenance impact values ​​corresponding to the same high-risk pipe section, and determine the existence area corresponding to the minimum post-maintenance impact value as the area currently undergoing maintenance; The associated area of ​​each pipeline defect existing area in a single high-risk pipeline section is determined repeatedly based on the target finite element model until all high-risk pipeline sections are overhauled.

[0064] Optionally, the defect repair module 15 is specifically used for: Obtain historical pipeline defects that induce natural gas leakage in a single high-risk pipeline section, count the second occurrence times of each historical pipeline defect, and select the third historical pipeline defect from each historical pipeline defect in descending order of the second occurrence times to determine it as the corresponding key leakage defect; The historical occurrence areas of each key leakage defect in the corresponding high-risk pipe section are counted, and the third occurrence times of each historical occurrence area are counted. In descending order of the third occurrence times, the fourth number of historical occurrence areas are selected from each historical occurrence area to determine as the corresponding key leakage defect prone area; Calculate the third weight of the key leakage defect of a single high-risk pipe section and the fourth weight of the corresponding prone area, where the third weight is the ratio of the second occurrence number of the single key leakage defect to the sum of the second occurrence numbers of all key leakage defects, and the fourth weight is the ratio of the third occurrence number of the single prone area corresponding to the key leakage defect to the sum of the third occurrence numbers of all corresponding prone areas; The high-risk pipe section with associated areas is determined as the key focus pipe section, and the weight coefficient of the associated area in the key focus pipe section is calculated based on the third weight and the corresponding fourth weight of the key focus pipe section, and the increased stress value of each associated area in the same key focus pipe section is multiplied by the corresponding weight coefficient and summed to obtain the corresponding initial post-inspection impact value; The weighted sum of each initial post-inspection impact value is performed to obtain the post-inspection impact value of the corresponding existing area.

[0065] Optionally, the defect repair module 15 is specifically used for: Calculate the product of the third weight of the pipeline defect in the target associated area in the focused pipe section and the second weight of the fourth weight of the corresponding target associated area, the pipeline defect in the target associated area is the key leakage defect corresponding to the focused pipe section, and the target associated area is the prone area corresponding to the focused pipe section; The second weight product is multiplied by 1 to obtain a weight coefficient of the corresponding target associated area, and the weight coefficient of the associated area other than the target associated area in the focused pipe section is determined to be 1.

[0066] It should be noted that the natural gas pipeline operation reliability analysis device provided in the above embodiment only uses the division of the above functional modules as an example when executing the natural gas pipeline operation reliability analysis method. In actual applications, the above functions can be assigned to different functional modules as needed, that is, the internal structure of the device is divided into different functional modules to complete all or part of the functions described above. In addition, the natural gas pipeline operation reliability analysis device provided in the above embodiment and the natural gas pipeline operation reliability analysis method embodiment belong to the same concept, and the implementation process thereof is detailed in the method embodiment, which will not be repeated here.

[0067] The embodiment of the present application further discloses a computer-readable storage medium, and the computer-readable storage medium stores a computer program, wherein when the computer program is executed by a processor, a natural gas pipeline operation reliability analysis method of the above embodiment is adopted.

[0068] Among them, the computer program can be stored in a computer-readable medium, the computer program includes computer program code, the computer program code can be in the form of source code, object code, executable file or certain middleware, etc. The computer-readable medium includes any entity or device that can carry the computer program code, recording medium, USB flash drive, mobile hard disk, magnetic disk, optical disk, computer memory, read-only memory (ROM), random access memory (RAM), electrical carrier signal, telecommunication signal and software distribution medium, etc. It should be noted that the computer-readable medium includes but is not limited to the above-mentioned components.

[0069] Among them, through this computer-readable storage medium, a natural gas pipeline operation reliability analysis method of the above embodiment is stored in a computer-readable storage medium, and is loaded and executed on a processor to facilitate the storage and application of the above method.

[0070] The embodiment of the present application also discloses an electronic device, in which a computer program is stored in a computer-readable storage medium. When the computer program is loaded and executed by a processor, the above-mentioned natural gas pipeline operation reliability analysis method is adopted.

[0071] The electronic device may be a desktop computer, a laptop computer, a cloud server or other electronic device, and the electronic device includes but is not limited to a processor and a memory. For example, the electronic device may also include input and output devices, a network access device, and a bus.

[0072] Among them, the processor can adopt a central processing unit (CPU). Of course, according to actual usage, other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. can also be adopted. The general-purpose processor can adopt a microprocessor or any conventional processor, etc., and this application does not impose any restrictions on this.

[0073] Among them, the memory can be an internal storage unit of the electronic device, such as a hard disk or memory of the electronic device, or it can be an external storage device of the electronic device, such as a plug-in hard disk, a smart memory card (SMC), a secure digital card (SD) or a flash memory card (FC) equipped on the electronic device. Moreover, the memory can also be a combination of an internal storage unit and an external storage device of the electronic device. The memory is used to store computer programs and other programs and data required by the electronic device. The memory can also be used to temporarily store data that has been output or is to be output, and this application does not impose any restrictions on this.

[0074] Among them, through this electronic device, a natural gas pipeline operation reliability analysis method of the above embodiment is stored in the memory of the electronic device, and is loaded and executed on the processor of the electronic device for easy use.

[0075] The above is only an exemplary embodiment of the present disclosure, and the scope of the present disclosure cannot be limited thereto. That is, any equivalent changes and modifications made according to the teachings of the present disclosure are still within the scope of the present disclosure. After considering the specification and practicing the disclosure here, those skilled in the art will easily think of other embodiments of the present disclosure. This application is intended to cover any modification, use or adaptation of the present disclosure, which follows the general principles of the present disclosure and includes common knowledge or customary technical means in the technical field not recorded in the present disclosure. The description and examples are only regarded as exemplary, and the scope and spirit of the present disclosure are defined by the claims.

Claims

1. A method for analyzing the reliability of natural gas pipeline operation, characterized in that: The method comprises: Acquire at least one target pipe section of a pipeline defect existing in a natural gas pipeline, wherein the pipeline defect is a defect inducing natural gas leakage; Determine at least one leak-prone pipe section and a corresponding leak-prone defect from each pipe section of the natural gas pipeline, wherein the leak-prone pipe section is a pipe section of the natural gas pipeline where natural gas leakage is likely to occur, and the leak-prone defect is a defect in the leak-prone pipe section that is likely to induce natural gas leakage; When the target pipe section is a leak-prone pipe section and the existing pipeline defect is a corresponding leak-prone defect, the corresponding target pipe section is determined as a key pipe section, and based on the leak-prone defect existing in the key pipe section, a risk coefficient of leakage of the key pipe section is determined; Based on the total number of historical leakages of the key pipeline section, the number of recent leakages within a preset time before the current time and the risk coefficient, the leakage risk level of the key pipeline section is determined by a preset risk level calculation formula, and when the leakage risk level exceeds a preset risk level threshold, the key pipeline section is determined as a high-risk pipeline section.

2. The method for analyzing the operation reliability of a natural gas pipeline according to claim 1, characterized in that: The risk level calculation formula is: ； In the formula, R represents the leakage risk level of the key pipeline section, S represents the risk factor of leakage in the key pipeline section, Indicates the number of recent leaks in the key pipe section within the preset time before the current time. represents the total number of historical leakages in the key pipe section, T represents the duration corresponding to the preset time, Indicates the adjustment parameters, which adjust the impact of the recent leakage times on the current leakage risk level of the key pipeline section. Indicates the adjustment parameters, which adjust the impact of the total number of historical leakages on the current leakage risk level of the key pipeline section. A scaling parameter that represents the impact of the total number of historical leaks on the current leakage risk level of the key pipeline section.

3. The method for analyzing the operation reliability of a natural gas pipeline according to claim 1, characterized in that: The determining of at least one leak-prone pipe section and a corresponding leak-prone defect from each pipe section of the natural gas pipeline specifically includes: Obtain the total number of historical natural gas leakages of each pipe section of the natural gas pipeline, and select the pipe section with the first number from each pipe section in descending order of the total number of historical leakages and determine it as a pipe section prone to leakage; Obtaining historical pipeline defects that induce natural gas leakage in each of the leaky pipe sections, counting the first occurrence times of each of the historical pipeline defects, and selecting the historical pipeline defect with the second occurrence times from each of the historical pipeline defects in descending order as the leaky defect of the corresponding leaky pipe section; The step of determining the risk factor of leakage of the key pipe section based on the leakage-prone defects in the key pipe section specifically includes: Determine a first weight of the key pipe section and a second weight of each existing leak-prone defect, wherein the first weight is the ratio of the total number of historical leakages of the key pipe section to the total number of historical leakages of all leak-prone pipe sections, and the second weight is the ratio of the first occurrence number of the leak-prone defect existing in the key pipe section to the sum of the first occurrence numbers of all corresponding leak-prone defects; The first weight and the first weight product of each corresponding second weight are calculated, and the first weight products are summed to obtain the risk coefficient of leakage of the key pipe section.

4. The method for analyzing the reliability of natural gas pipeline operation according to claim 1, characterized in that: The method further comprises: Get the wind direction and wind speed at the current time; Based on the wind direction, determining the nearest target leakage monitoring point downstream of each high-risk pipe section; Based on the wind speed, determine the diffusion time of natural gas from each high-risk pipeline section to the corresponding target leakage monitoring point, and determine the maintenance order of the corresponding high-risk pipeline section according to the diffusion time. The longer the diffusion time, the earlier the corresponding maintenance order. Based on the maintenance sequence, each pipeline defect in the corresponding high-risk pipeline section is repaired in turn.

5. The method for analyzing the operation reliability of a natural gas pipeline according to claim 4, characterized in that: The repairing of each pipeline defect in the corresponding high-risk pipeline section in sequence based on the repair sequence specifically includes: When the pipeline defect is pipeline outer wall corrosion, determining a target finite element model corresponding to the natural gas pipeline; Based on the target finite element model, determining the associated region of each existing region of the pipeline defect in the single high-risk pipe section, wherein the associated region is the region where the pipeline defect with increased stress value in each high-risk pipe section is located after the corresponding existing region is eliminated from stress concentration; Determine the post-repair impact value of the corresponding existing area according to the increased stress values ​​of each associated area corresponding to each existing area; Selecting the minimum post-maintenance impact value from the post-maintenance impact values ​​corresponding to the same high-risk pipe section, and determining the existence area corresponding to the minimum post-maintenance impact value as the area currently undergoing maintenance; The process of determining the associated region of each pipeline defect existing region in a single high-risk pipeline section based on the target finite element model is repeated until all the high-risk pipeline sections are overhauled.

6. The method for analyzing the reliability of natural gas pipeline operation according to claim 5, characterized in that: The step of determining the impact value of the corresponding existing area after leak detection and repair according to the increased stress values ​​of each associated area corresponding to each existing area specifically includes: Obtaining historical pipeline defects that induce natural gas leakage in a single high-risk pipeline section, counting the second occurrence times of each of the historical pipeline defects, and selecting the third historical pipeline defect from each of the historical pipeline defects in descending order of the second occurrence times to determine as the corresponding key leakage defect; Counting the historical occurrence areas of each of the key leakage defects in the corresponding high-risk pipe section, and counting the third occurrence times of each of the historical occurrence areas, and selecting the fourth number of historical occurrence areas from each of the historical occurrence areas in descending order of the third occurrence times to determine as the corresponding key leakage defect prone-to-occur area; Calculate the third weight of the key leakage defect of the single high-risk pipe section and the fourth weight of the corresponding prone area, the third weight is the ratio of the second occurrence number of the single key leakage defect to the sum of the second occurrence numbers of all key leakage defects, and the fourth weight is the ratio of the third occurrence number of the single prone area corresponding to the key leakage defect to the sum of the third occurrence numbers of all corresponding prone areas; The high-risk pipe section with the associated area is determined as a key focus pipe section, and based on the third weight and the corresponding fourth weight of the key focus pipe section, the weight coefficient of the associated area in the key focus pipe section is calculated, and the increased stress value of each associated area in the same key focus pipe section is multiplied by the corresponding weight coefficient and summed to obtain the corresponding initial post-inspection impact value; The weighted sum of the initial post-inspection impact values ​​is performed to obtain the post-inspection impact value of the corresponding existing area.

7. The method for analyzing the reliability of natural gas pipeline operation according to claim 6, characterized in that: The calculating, based on the third weight of the focused pipe segment and the corresponding fourth weight, the weight coefficient of the associated area in the focused pipe segment specifically includes: Calculate the second weight product of the third weight of the pipeline defect in the target associated area in the focused pipe section and the fourth weight of the corresponding target associated area, the pipeline defect in the target associated area is the key leakage defect corresponding to the focused pipe section, and the target associated area is the prone area corresponding to the focused pipe section; The second weight product is multiplied by 1 to obtain a weight coefficient of the corresponding target associated area, and the weight coefficient of the associated area other than the target associated area in the focused pipe segment is determined to be 1.

8. A natural gas pipeline operation reliability analysis device, characterized in that: include: A pipe section acquisition module (11) is used to acquire at least one target pipe section of a pipeline defect existing in a natural gas pipeline, wherein the pipeline defect is a defect that induces natural gas leakage; A defect determination module (12) is used to determine at least one leak-prone pipe section and a corresponding leak-prone defect from each pipe section of the natural gas pipeline, wherein the leak-prone pipe section is a pipe section of the natural gas pipeline where natural gas leakage is likely to occur, and the leak-prone defect is a defect in the leak-prone pipe section that is likely to induce natural gas leakage; A coefficient calculation module (13) is used to determine the corresponding target pipe section as a key pipe section when the target pipe section is a leak-prone pipe section and the existing pipeline defect is a corresponding leak-prone defect, and determine the risk coefficient of leakage of the key pipe section based on the leak-prone defect existing in the key pipe section; The risk identification module (14) is used to determine the leakage risk level of the key pipe section based on the total number of historical leakages of the key pipe section, the number of recent leakages within a preset time before the current time and the risk coefficient, using a preset risk level calculation formula, and when the leakage risk level exceeds a preset risk level threshold, determine the key pipe section as a high-risk pipe section.

9. A computer-readable storage medium having a computer program stored therein, characterized in that: When the computer program is loaded and executed by a processor, the method according to any one of claims 1 to 7 is adopted.

10. An electronic device comprising a memory, a processor, and a computer program stored in the memory and capable of running on the processor, characterized in that: When the processor loads and executes the computer program, the method according to any one of claims 1 to 7 is adopted.

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