Pipeline leak location correction method, system, electronic device and storage medium

Abstract

The application discloses a pipeline leakage positioning correction method, comprising the following steps: S110, determining an initial leakage position by using a conventional pipeline leakage positioning method; S120, analyzing leakage errors to determine a leakage position range; S130, collecting data information of a pipe section in the leakage position range, judging whether there is a corrosion defect and historical detection data thereof; if there is a corrosion defect and historical detection data thereof, entering step S141; if there is no corrosion defect or lacks historical detection data, entering step S142; S141, calculating a corrosion rate, judging whether the corrosion defect is perforated or over-pressured, if yes, determining a leakage point position; if no, entering step S142; S142, analyzing a corrosion risk, and determining a point with the largest corrosion risk as the leakage point position. The application further discloses a pipeline leakage positioning correction system, an electronic device and a storage medium. The application determines the leakage point position from multiple angles such as leakage causes and corrosion occurrence rules, and effectively improves the accuracy of leakage positioning.

Description

Technical Field

[0001] This invention relates to the field of leak detection and location technology, and in particular to a pipeline leak location and correction method, system, electronic device and storage medium. Background Technology

[0002] In recent years, leaks have frequently occurred in both oilfield gathering and transportation pipelines and long-distance oil and gas transmission pipelines due to their long service life and the interaction of internal and external corrosion factors, causing huge economic losses and significant social impacts to enterprises. Effectively identifying and locating leaks is crucial to preventing leaks from occurring or spreading and reducing losses; it is also a pressing technical challenge for oil and gas pipeline companies. While industry and academia have conducted extensive research on pipeline leak detection and location in recent years, and the resulting technologies have been explored and applied in major pipeline companies, significant location errors still exist.

[0003] The information disclosed in this background section is intended only to enhance the understanding of the overall background of the invention and should not be construed as an admission or in any way implying that the information constitutes prior art known to those skilled in the art. Summary of the Invention

[0004] One of the objectives of this invention is to provide a pipeline leak location correction method, system, electronic device, and storage medium, thereby improving the problem of low location accuracy in existing leak detection technologies.

[0005] To achieve the above objectives, according to a first aspect of the present invention, the present invention provides a method for locating and correcting pipeline leaks, comprising the following steps:

[0006] S110 uses conventional pipeline leak location methods to determine the initial leak location;

[0007] S120 analyzes leakage errors to determine the location and range of the leakage.

[0008] S130 collects data on the pipe section within the leak location area to determine whether corrosion defects exist and its historical detection data:

[0009] If corrosion defects and their historical detection data exist, proceed to step S141;

[0010] If there are no corrosion defects or historical testing data is lacking, proceed to step S142;

[0011] S141 calculates the corrosion rate and determines whether corrosion defects result in perforation or overpressure.

[0012] If so, the corrosion defect will be identified as the location of the leak.

[0013] If not, proceed to step S142;

[0014] S142 analyzes corrosion risk and identifies the point with the highest corrosion risk as the leak location.

[0015] Furthermore, in the above technical solution, step S130 includes combining historical detection data to find whether there are corrosion defects in the pipe section within the range of the leak location.

[0016] Furthermore, in the above technical solution, step S141 includes calculating the remaining wall thickness of the current corrosion defect based on the corrosion rate of the pipe section and the size of the corrosion defect, and determining whether the corrosion defect has perforated.

[0017] Furthermore, in the above technical solution, step S141 also includes calculating the remaining strength of the corrosion defect and determining whether the pipeline is overpressured based on the operating pressure at the location of the corrosion defect.

[0018] Furthermore, in the above technical solution, step S142 includes dividing the pipe segment within the leakage location range into multiple pipe segment units and analyzing the corrosion risk of each pipe segment unit.

[0019] Furthermore, in the above technical solution, the midpoint of the pipe section unit with the highest corrosion risk is determined as the leak point.

[0020] Furthermore, in the above technical solution, the data information of the pipe section within the leakage location range includes pipeline basic information, pipeline operating condition data, internal corrosion environment data, external corrosion environment data, and historical detection data.

[0021] Furthermore, in the above technical solution, the pipeline basic information includes pipe diameter, wall thickness, material, burial depth, mileage, elevation, design coefficient, design pressure, maximum allowable working pressure, and service life; pipeline operating condition data includes operating pressure, operating temperature, transported medium, and flow rate; internal corrosion environment data includes medium temperature, flow velocity, H2S content, CO2 content, salinity, moisture content, dissolved oxygen content, and pH value; external corrosion environment data includes soil resistivity, redox potential, pipe-to-soil potential, soil moisture content, soil salinity, and soil pH value; and historical detection data includes the location and size of pipeline corrosion defects.

[0022] Furthermore, in the above technical solution, the corrosion rate is obtained by superimposing the internal corrosion rate and the external corrosion rate.

[0023] Furthermore, in the above technical solution, the calculation of corrosion rate includes using principal component analysis, grey relational analysis or mutual information theory to perform data correlation analysis, screen and determine the main influencing factors of internal and external corrosion respectively, and use neural networks and random forest algorithms to establish prediction models for internal and external corrosion rates.

[0024] Furthermore, in the above technical solution, the analysis of corrosion risk includes: analyzing the occurrence pattern of pipeline corrosion based on historical pipeline corrosion data, extracting the characteristics of corrosion-prone areas, and thus determining the sensitive factors of corrosion risk; and using the Apriori algorithm to determine the strong correlation rules of pipeline corrosion and establish a corrosion risk calculation model.

[0025] According to a second aspect of the present invention, the present invention provides a pipeline leak location and correction system, comprising: a data acquisition unit for acquiring data information of pipe segments within the leak location range; a data processing unit for determining the initial leak location using conventional pipeline leak location methods, analyzing leak errors, and determining the leak location range; an analysis unit for calculating corrosion rates and / or analyzing corrosion risks of pipe segments within the leak location range; and a result output unit for determining the leak point location based on the analysis results of the analysis unit.

[0026] According to a third aspect of the present invention, an electronic device is provided, comprising: at least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, the instructions being executed by the at least one processor to cause the at least one processor to perform a pipeline leak location and correction method as described in any of the above technical solutions.

[0027] According to a fourth aspect of the present invention, the present invention provides a non-transitory computer-readable storage medium storing computer-executable instructions for causing a computer to perform a pipeline leak location and correction method as described in any of the above technical solutions.

[0028] Compared with the prior art, the present invention has one or more of the following beneficial effects:

[0029] 1. This invention determines the location of the leak point from multiple perspectives, including the causes of leakage and the laws governing corrosion, thus avoiding the location deviation caused by the singularity of traditional leak location methods or insufficient raw data, and effectively improving the accuracy of leak location.

[0030] 2. This invention combines leak detection with corrosion analysis. Based on the preliminary leak location using existing methods, it also considers the direct cause of the leak due to corrosion, and further improves the accuracy of leak location by combining corrosion risk factor analysis and risk magnitude determination.

[0031] 3. The corrosion analysis of this invention can provide a reference for pipeline corrosion analysis and prediction, and further provide a basis for pipeline maintenance decisions.

[0032] The above description is merely an overview of the technical solution of the present invention. In order to better understand the technical means of the present invention and to implement it according to the contents of the specification, and to make the above and other objects, technical features and advantages of the present invention easier to understand, one or more preferred embodiments are listed below and described in detail with reference to the accompanying drawings. Attached Figure Description

[0033] Figure 1 This is a schematic flowchart of a pipeline leak location and correction method according to an embodiment of the present invention.

[0034] Figure 2 This is a schematic diagram of a pipeline leak location and correction system according to an embodiment of the present invention.

[0035] Figure 3 This is a schematic diagram of the hardware structure of an electronic device for performing a pipeline leak location and correction method according to an embodiment of the present invention. Detailed Implementation

[0036] The specific embodiments of the present invention will now be described in detail with reference to the accompanying drawings, but it should be understood that the scope of protection of the present invention is not limited to the specific embodiments.

[0037] Unless otherwise expressly stated, throughout the specification and claims, the term "comprising" or its variations such as "including" or "comprises" shall be understood to include the stated elements or components without excluding other elements or other components.

[0038] In this document, for ease of description, spatial relative terms such as “below,” “under,” “down,” “above,” “above,” “up,” etc., are used to describe the relationship of one element or feature to another element or feature in the accompanying drawings. It should be understood that spatial relative terms are intended to encompass different orientations of an object in use or operation, in addition to those depicted in the figures. For example, if an object in the figure is flipped, an element described as “below” or “under” another element or feature would be oriented “above” that element or feature. Thus, the exemplary term “below” can encompass both the downward and upward orientations. An object may also have other orientations (rotated 90 degrees or other orientations), and the spatial relative terms used herein should be interpreted accordingly.

[0039] In this document, the terms "first," "second," etc., are used to distinguish two different elements or parts, and are not used to define specific positions or relative relationships. In other words, in some embodiments, the terms "first," "second," etc., can also be used interchangeably.

[0040] Based on traditional leak location methods, this invention preliminarily determines the leak range by incorporating location errors. Within the leak-affected pipe section, corrosion analysis is performed based on the cause of the leak. On one hand, by calculating the corrosion rate and combining it with the corrosion size information obtained from detection, it determines whether there are corrosion perforation points or wall thinning overpressure points. On the other hand, by analyzing the corrosion occurrence patterns through historical corrosion data, a strong corrosion correlation rule is established to determine the corrosion risk of the leak-affected pipe section. Finally, the location of the leak point is determined by combining the calculation and analysis results.

[0041] like Figure 1 As shown, the pipeline leakage location and correction method according to a specific embodiment of the present invention includes the following steps:

[0042] S110 uses conventional pipeline leak location methods to determine the initial leak location;

[0043] S120 analyzes leakage errors to determine the location and range of the leakage.

[0044] S130 collects data on the pipe section within the leak location area to determine whether corrosion defects exist and its historical detection data:

[0045] If corrosion defects and their historical detection data exist, proceed to step S141;

[0046] If there are no corrosion defects or historical testing data is lacking, proceed to step S142;

[0047] S141 calculates the corrosion rate and determines whether corrosion defects result in perforation or overpressure.

[0048] If so, the corrosion defect will be identified as the location of the leak.

[0049] If not, proceed to step S142;

[0050] S142 analyzes corrosion risk and identifies the point with the highest corrosion risk as the leak location.

[0051] Furthermore, in one or more exemplary embodiments of the present invention, a conventional pipeline leak location method may employ, for example, the negative pressure wave method, the specific formula of which is as follows:

[0052]

[0053] Where X is the distance from the leak point to the upstream detection point, in meters; L is the pipe length, in meters; T1 and T2 are the times when the upstream and downstream sensors receive the pressure wave signals, in seconds; α(t) is the propagation speed of the pressure wave in the pipe at oil temperature t, in meters per second; K(t) is the bulk elastic coefficient of crude oil at oil temperature t, in Pa; D is the pipe diameter, in meters; e is the pipe wall thickness, in meters; and C is a correction coefficient related to the pipe constraint conditions.

[0054] Furthermore, in one or more exemplary embodiments of the present invention, the leakage location error is analyzed by combining the characteristics and influence laws of parameter values ​​in the negative pressure wave location method to determine the leakage location range, for example, it can be denoted as [X-X', X+X'].

[0055] Furthermore, in one or more exemplary embodiments of the present invention, step S130 includes combining historical detection data to determine whether there are corrosion defects in the pipe section within the leakage location area. The absence of corrosion defects or the lack of historical detection data includes two scenarios: the first is that the pipeline underwent defect detection, but no corrosion defects were detected within the leakage location area; the second is that no defect detection was performed, and it is unknown whether corrosion defects exist within the leakage location area. In both of these scenarios, it is impossible to determine whether there is perforation or overpressure within the leakage location area.

[0056] Furthermore, in one or more exemplary embodiments of the present invention, step S141 includes calculating the remaining wall thickness of the current corrosion defect based on the corrosion rate of the pipe section and the size of the corrosion defect, and determining whether the corrosion defect has perforated.

[0057] Furthermore, in one or more exemplary embodiments of the present invention, step S141 further includes calculating the remaining strength of the corrosion defect and determining whether the pipeline is overpressured based on the operating pressure at the location of the corrosion defect.

[0058] Furthermore, in one or more exemplary embodiments of the present invention, step S142 includes dividing the pipe segment within the leakage location range into multiple smaller pipe segment units, analyzing the corrosion risk of each pipe segment unit, and determining the midpoint of the pipe segment unit with the highest corrosion risk as the leakage point location. It should be noted that the smaller the pipe segment unit, the more accurate the correction result for the leakage location, but the computational workload is larger. Therefore, in practical applications, the pipe segment unit division can be determined according to on-site requirements, and the present invention is not limited thereto.

[0059] Furthermore, in one or more exemplary embodiments of the present invention, all relevant data required for pipeline corrosion analysis are aligned and integrated according to time and spatial information and then uniformly stored in a database. Data information for the pipe section within the leakage location range includes pipeline basic information, pipeline operating condition data, internal corrosion environment data, external corrosion environment data, and detection data. Pipeline basic information includes pipe diameter, wall thickness, material, burial depth, mileage, elevation, design coefficient, design pressure, maximum allowable working pressure, and service life, etc.; pipeline operating condition data includes operating pressure, operating temperature, transported medium, and flow rate, etc.; internal corrosion environment data includes medium temperature, flow velocity, H2S content, CO2 content, salinity, moisture content, dissolved oxygen content, and pH value, etc.; external corrosion environment data includes soil resistivity, redox potential, pipe-to-soil potential, soil moisture content, soil salinity, and soil pH value, etc.; detection data includes the location and size of pipeline corrosion defects, etc.

[0060] Furthermore, in one or more exemplary embodiments of the present invention, the corrosion rate refers to the comprehensive corrosion rate, which is obtained by superimposing the internal corrosion rate and the external corrosion rate. Calculating the corrosion rate includes performing data association analysis using principal component analysis, grey relational analysis, or mutual information theory to screen and determine the main influencing factors of internal and external corrosion, and establishing prediction models for internal and external corrosion rates using neural networks and random forest algorithms.

[0061] Furthermore, in one or more exemplary embodiments of the present invention, the analysis of corrosion risk includes: analyzing the occurrence pattern of pipeline corrosion based on historical pipeline corrosion data, extracting the characteristics of corrosion-prone areas, thereby determining the sensitive factors of corrosion risk; and using the Apriori algorithm to determine the strong correlation rules of pipeline corrosion and establish a corrosion risk calculation model.

[0062] Combination Figure 2 As shown, in one or more embodiments of the present invention, the pipeline leak location correction system includes: a data acquisition unit 10, which is used to acquire data information of the pipe segment within the leak location range; a data processing unit 20, which is used to determine the initial leak location using conventional pipeline leak location methods, analyze the leak error, and determine the leak location range; an analysis unit 30, which performs corrosion rate calculation and / or corrosion risk analysis on the pipe segment within the leak location range; and a result output unit 40, which determines the leak point location based on the analysis results of the analysis unit.

[0063] The pipeline leak location and correction method, system, electronic device and storage medium of the present invention are described in more detail below by way of specific embodiments. It should be understood that the embodiments are merely exemplary and the present invention is not limited thereto.

[0064] Example 1

[0065] This embodiment employs the pipeline leak location correction method of the present invention for pipeline leak location. The initial leak location is determined using the negative pressure wave method. Leakage error is analyzed to determine the leak location range. Data information of the pipe section within the leak location range is collected. Historical detection data shows the presence of corrosion defects within the leak location range. Based on the location information of the corrosion defects, the corresponding comprehensive corrosion rate is determined. This allows calculation of whether perforation has occurred from the detection time to the current time. Furthermore, based on the corrosion defect size information and corrosion rate, the size of the defect at the current time is calculated. Then, the pipeline residual strength calculation model is used to calculate the pipeline residual strength corresponding to the current defect size at the current time. Simultaneously, the operating pressure at the defect point is obtained from the detected defect location information. By comparing the current defect residual strength with the operating pressure, it is determined whether overpressure bursting has occurred at the defect point. If perforation or overpressure has occurred due to the corrosion defect, the location of the corrosion defect is determined as the leak point. If no perforation or overpressure has occurred due to the corrosion defect, the corrosion risk is further analyzed, and the point with the highest corrosion risk is determined as the leak point.

[0066] Example 2

[0067] This embodiment uses the pipeline leak location correction method of the present invention to locate a pipeline leak. A conventional pipeline leak location method is used to determine the initial leak location. Leakage error is analyzed to determine the range of the leak location. Data information of the pipe segments within the leak location range is collected and corrosion analysis is performed. Since historical detection data is lacking in this embodiment, a corrosion risk analysis is conducted on the pipe segments within the leak location range. First, the pipe segments within the leak location range are divided into multiple pipe segment units. Then, the corrosion risk of each pipe segment unit is analyzed, and the midpoint of the pipe segment unit with the highest corrosion risk is determined as the leak point location.

[0068] In corrosion risk analysis, corrosion points, butt welds, elevation changes, areas of strong erosion, areas with stray current interference, pipe junctions, and historical defect points are considered as features to be associated. Based on these features, historical data collected on-site is organized. For example, different features are numbered to obtain the transaction dataset required by the algorithm. For instance, each feature is numbered from 1 to 7, and an example of a transaction dataset related to corrosion points compiled from the data collected on-site is shown in Table 1 below.

[0069] Table 1. Examples of transaction datasets related to erosion points.

[0070] Serial Number Transaction dataset Number of occurrences 1 1,3 8 2 1,4,6 7 3 1,2,5,6 3 4 1,2,4,6,7 5 5 1,3,4,5,6,7 6 …… …… ……

[0071] The Apriori algorithm is used to iteratively search layer by layer, determining frequent itemsets based on support and confidence thresholds. Finally, the corrosion risk assessment model is determined by combining the support and confidence scores. For example, confidence can be used as the first determining factor, and support as the second. That is, the higher the confidence score in a frequent itemset, the greater the corrosion risk of the pipe segment unit with the corresponding characteristics. With the same confidence score, the higher the support score in a frequent itemset, the greater the corrosion risk of the pipe segment unit with the corresponding characteristics. This method identifies the pipe segment unit with the highest corrosion risk within the leakage area.

[0072] Example 3

[0073] This embodiment provides a non-transitory (non-volatile) computer storage medium that stores computer-executable instructions that can execute the methods in any of the above method embodiments and achieve the same technical effect.

[0074] Example 4

[0075] This embodiment provides a computer program product, which includes a computer program stored on a non-transitory computer-readable storage medium. The computer program includes program instructions, which, when executed by a computer, cause the computer to perform the methods described above and achieve the same technical effects.

[0076] Example 5

[0077] Figure 3 This is a schematic diagram of the hardware structure of the electronic device for executing the pipeline leak location and correction method according to this embodiment. The device includes one or more processors 610 and a memory 620. Taking one processor 610 as an example, the device may also include an input device 630 and an output device 640.

[0078] The processor 610, memory 620, input device 630, and output device 640 can be connected via a bus or other means. Figure 3 Taking the example of a connection between China and Israel via a bus.

[0079] The memory 620, as a non-transitory computer-readable storage medium, can be used to store non-transitory software programs, non-transitory computer-executable programs, and modules. The processor 610 executes various functional applications and data processing of the electronic device by running the non-transitory software programs, instructions, and modules stored in the memory 620, thereby implementing the processing method of the above-described method embodiments.

[0080] The memory 620 may include a program storage area and a data storage area, wherein the program storage area may store the operating system and applications required for at least one function; the data storage area may store data, etc. Furthermore, the memory 620 may include high-speed random access memory, and may also include non-transitory memory, such as at least one disk storage device, flash memory device, or other non-transitory solid-state storage device. In some embodiments, the memory 620 may optionally include memory remotely located relative to the processor 610, and these remote memories may be connected to the processing device via a network. Examples of such networks include, but are not limited to, the Internet, intranets, local area networks, mobile communication networks, and combinations thereof.

[0081] Input device 630 can receive input digital or character information and generate signal input. Output device 640 may include display devices such as a display screen.

[0082] One or more modules are stored in memory 620 and, when executed by one or more processors 610, execute:

[0083] S110 uses conventional pipeline leak location methods to determine the initial leak location;

[0084] S120 analyzes leakage errors to determine the location and range of the leakage.

[0085] S130 collects data on the pipe section within the leak location area to determine whether corrosion defects exist and its historical detection data:

[0086] If corrosion defects and their historical detection data exist, proceed to step S141;

[0087] If there are no corrosion defects or historical testing data is lacking, proceed to step S142;

[0088] S141 calculates the corrosion rate and determines whether corrosion defects result in perforation or overpressure.

[0089] If so, the corrosion defect will be identified as the location of the leak.

[0090] If not, proceed to step S142;

[0091] S142 analyzes corrosion risk and identifies the point with the highest corrosion risk as the leak location.

[0092] The above-described product can execute the methods provided in the embodiments of the present invention, and has the corresponding functional modules and beneficial effects for executing the methods. Technical details not described in detail in this embodiment can be found in the methods provided in other embodiments of the present invention.

[0093] The device embodiments described above are merely illustrative. The units described as separate components may or may not be physically separate, and the components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the modules can be selected to achieve the purpose of this embodiment according to actual needs.

[0094] Through the above description of the embodiments, those skilled in the art can clearly understand that each embodiment can be implemented by means of software plus a general-purpose hardware platform, and of course, it can also be implemented by hardware. Based on this understanding, the above technical solutions, in essence or the parts that contribute to the related technology, can be embodied in the form of a software product. This computer software product can be stored in a computer-readable storage medium, such as ROM / RAM, magnetic disk, optical disk, etc., including several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute the methods of various embodiments or some parts of embodiments.

[0095] The foregoing description of specific exemplary embodiments of the present invention is for illustrative and explanatory purposes. These descriptions are not intended to limit the invention to the precise forms disclosed, and it will be apparent that many changes and variations can be made in accordance with the foregoing teachings. The exemplary embodiments were chosen and described in order to explain the specific principles of the invention and its practical application, thereby enabling those skilled in the art to implement and utilize various different exemplary embodiments of the invention, as well as various different choices and variations. Any simple modifications, equivalent changes, and alterations made to the foregoing exemplary embodiments should fall within the scope of protection of the present invention.

Claims

1. A method for locating and correcting pipeline leaks, characterized in that, Includes the following steps: S110 uses conventional pipeline leak location methods to determine the initial leak location; S120 analyzes leakage errors to determine the location and range of the leakage. S130 collects data on the pipe section within the leak location area to determine whether corrosion defects exist and its historical detection data: If corrosion defects and their historical detection data exist, proceed to step S141; If there are no corrosion defects or historical testing data is lacking, proceed to step S142; Step S130 includes combining historical detection data to find whether there are corrosion defects in the pipe section within the range of the leak location; S141 calculates the corrosion rate and determines whether corrosion defects result in perforation or overpressure. If so, the corrosion defect will be identified as the location of the leak. If not, proceed to step S142; S142 analyzes corrosion risk and identifies the point with the highest corrosion risk as the leak location. Step S142 includes dividing the pipe section within the leak location range into multiple pipe section units and analyzing the corrosion risk of each pipe section unit. The analysis of corrosion risk includes: analyzing the occurrence pattern of pipe corrosion based on historical pipeline corrosion data, extracting the characteristics of corrosion-prone areas, and thus determining the sensitive factors of corrosion risk. In addition, we determined the strong correlation rules for pipeline corrosion and established a corrosion risk calculation model.

2. The pipeline leakage location and correction method according to claim 1, characterized in that, Step S141 includes calculating the remaining wall thickness of the current corrosion defect based on the corrosion rate of the pipe section and the size of the corrosion defect, and determining whether the corrosion defect has perforated.

3. The pipeline leakage location and correction method according to claim 2, characterized in that, Step S141 also includes calculating the remaining strength of the corrosion defect and determining whether the pipeline is overpressured based on the operating pressure at the location of the corrosion defect.

4. The pipeline leak location and correction method according to claim 1, characterized in that, The midpoint of the pipe section with the highest corrosion risk was identified as the leak point.

5. The pipeline leak location and correction method according to claim 1, characterized in that, Data information for the pipe section within the leak location range includes pipeline foundation information, pipeline operating condition data, internal corrosion environment data, external corrosion environment data, and historical monitoring data.

6. The pipeline leakage location and correction method according to claim 5, characterized in that, Basic pipeline information includes pipe diameter, wall thickness, material, burial depth, mileage, elevation, design coefficient, design pressure, maximum allowable working pressure, and service life; pipeline operating condition data includes operating pressure, operating temperature, transported medium, and flow rate; internal corrosion environment data includes medium temperature, flow velocity, H2S content, CO2 content, salinity, moisture content, dissolved oxygen content, and pH value; external corrosion environment data includes soil resistivity, redox potential, pipe-to-soil potential, soil moisture content, soil salinity, and soil pH value; historical monitoring data includes the location and size of pipeline corrosion defects.

7. The pipeline leakage location and correction method according to claim 1, characterized in that, The corrosion rate is obtained by superimposing the internal corrosion rate and the external corrosion rate.

8. The pipeline leak location and correction method according to claim 7, characterized in that, The calculation of corrosion rate involves data association analysis using principal component analysis, grey relational analysis, or mutual information theory to screen and determine the main influencing factors of internal and external corrosion, and to establish prediction models for internal and external corrosion rates using neural networks and random forest algorithms.

9. The pipeline leakage location and correction method according to claim 1, characterized in that, The steps for determining strong correlation rules for pipeline corrosion and establishing a corrosion risk calculation model specifically employ the Apriori algorithm.

10. A pipeline leak location and correction system, characterized in that, The method described in any one of claims 1 to 9 includes: The data acquisition unit is used to collect data information of the pipe section within the range of the leak location; The data processing unit is used to determine the initial leak location using conventional pipeline leak location methods, analyze the leak error, and determine the range of the leak location. The analysis unit calculates the corrosion rate and / or performs corrosion risk analysis on the pipe section within the leak location area; and The result output unit determines the location of the leak point based on the analysis results of the analysis unit.

11. An electronic device, characterized in that, include: At least one processor; as well as A memory communicatively connected to the at least one processor; wherein, The memory stores instructions that can be executed by the at least one processor to cause the at least one processor to perform the pipeline leak location and correction method as described in any one of claims 1 to 9.

12. A non-transitory computer-readable storage medium, characterized in that, The non-transitory computer-readable storage medium stores computer-executable instructions for causing the computer to perform the pipeline leak location and correction method as described in any one of claims 1 to 9.

Images