An electromagnetic monitoring system and method for oil and gas pipeline defects

Abstract

The present invention discloses an electromagnetic monitoring system and method for oil and gas pipeline defects, which relates to the technical field of oil and gas pipeline defect detection. The system integrates multiple monitoring and evaluation modules. First, a topological network structure analysis module is used to perform topological segmentation on the pipeline, establish monitoring points, and monitor the flow parameters of the medium inside the pipeline in real time. The first risk coefficient Fx1 is calculated based on the monitoring data, and a first early warning instruction is issued in time to screen the risk area. In addition, the electromagnetic eddy current density calculation and evaluation module is used to accurately evaluate and locate the risk area. The system also continuously monitors the external environmental parameters of the pipeline and the abnormal conditions of the pipeline connections in adjacent areas, calculates the second risk coefficient Fx2 and the third risk coefficient Fx3, and promptly detects abnormalities in the external environment of the pipeline and abnormalities in the connection, sorts and executes priority maintenance strategies, gives priority to high-risk areas, and improves the efficiency of maintenance work.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas pipeline defect detection, and in particular to an electromagnetic monitoring system and method for oil and gas pipeline defects. Background Art

[0002] The safety and reliability of oil and gas pipelines are crucial during their operation. However, they are often exposed to complex environmental conditions and multiple stress factors, making them prone to various defects and failures, such as corrosion, cracks, sediment accumulation, and fatigue cracks. If these defects are not discovered and addressed promptly, they can lead to serious leaks, resulting in environmental pollution and economic losses. Therefore, effective defect monitoring and assessment of oil and gas pipelines is particularly important.

[0003] Existing methods for defect detection in oil and gas pipelines primarily rely on electromagnetic testing. Electromagnetic methods such as eddy current testing and magnetic particle testing can effectively detect defects such as cracks and corrosion on pipeline interior walls. While these technologies can ensure pipeline safety to a certain extent, they have significant limitations in practical application.

[0004] First, traditional electromagnetic inspection technology primarily focuses on detecting defects on the inner wall of pipelines, but is relatively weak in detecting defects on the outer wall and joints. Factors such as vibration, displacement, and microbial corrosion on the outer wall of pipelines also significantly impact pipeline safety, but these factors are often overlooked in traditional electromagnetic inspection technology. This lack of monitoring of the outer wall of pipelines can lead to potential safety hazards being missed. Summary of the Invention

[0005] (1) Technical problems solved

[0006] In view of the deficiencies of the prior art, the present invention provides an electromagnetic monitoring system and method for oil and gas pipeline defects to solve the problems mentioned in the background technology.

[0007] (2) Technical solution

[0008] To achieve the above objectives, the present invention is implemented through the following technical solutions: An electromagnetic monitoring method for oil and gas pipeline defects, comprising the following steps:

[0009] Step 1: Collect geographic, engineering, and design data related to the oil and gas pipeline, including the pipeline's topological structure and coordinate information, to establish a first visualization dataset. After preprocessing the first visualization dataset, use CAD software to create a three-dimensional model of the oil and gas pipeline. The three-dimensional model includes the pipeline's topological network structure and the pipeline's surrounding environment.

[0010] Step 2: Segment the three-dimensional model of the oil and gas pipeline into a topological network structure. For each area, determine its adjacent areas and connection relationships, establish a topological relationship diagram between regions, set a first pipeline monitoring point, a first pipeline inner wall electromagnetic monitoring point, a second pipeline middle monitoring point, and a third pipeline outer wall monitoring point in each area, and set a fourth connection monitoring point at the connection between each area and the adjacent area pipeline;

[0011] Step 3: Collect the flow rate Ls, water content Lh, and inner wall temperature wd of the medium inside the pipeline to construct a first risk coefficient Fx1. If the first risk coefficient Fx1 is higher than the first risk threshold, send a first warning instruction to the outside.

[0012] Step 4: When the first warning instruction is received, the electromagnetic monitoring information of the inner wall of the pipeline in the current risk area is collected through the electromagnetic eddy current detector, the electromagnetic field is numerically solved by the finite element method, and the electromagnetic eddy current density of the current risk area is constructed. After evaluation, the defect coordinates are determined and the first significant mark is made in the 3D model of the oil and gas pipeline;

[0013] Step 5: Continuously obtain the pipeline outer wall vibration, displacement, and microbial corrosion data collected from the third pipeline outer wall monitoring point in each area, construct a second risk factor Fx2, and evaluate the second risk factor Fx2 to obtain a second evaluation result and a second strategy;

[0014] Step 6: Collect sediment accumulation data and fatigue crack data at the connection through the fourth connection monitoring point, construct a third risk coefficient Fx3, and evaluate the third risk coefficient Fx3 to obtain a third evaluation result and a third strategy.

[0015] Preferably, the topological network structure includes pipeline segments, connectors, valves, supports and ancillary facilities; using visualization technology and graphic rendering methods, the three-dimensional model of the oil and gas pipeline obtained by modeling is presented as a visual image, and the visual image displays the internal and external structure of the pipeline, as well as various data information related to the pipeline.

[0016] Preferably, the first pipeline monitoring point includes a first pipeline inner wall electromagnetic monitoring point, a second pipeline middle monitoring point and a third pipeline outer wall monitoring point;

[0017] The first pipeline inner wall electromagnetic monitoring point is used to install an electromagnetic eddy current detector and a magnetic resistance detector in the middle of the pipeline;

[0018] The monitoring point in the middle of the second pipeline is used to install a temperature sensor, a water content sensor, and a flow rate sensor;

[0019] Install stress sensors, displacement sensors, vibration sensors and microbial sensors at the monitoring points on the outer wall of the third pipeline;

[0020] Stress sensor: initial monitoring frequency is 1Hz;

[0021] Displacement sensor: initial detection frequency 1Hz;

[0022] Vibration sensor: initial monitoring frequency 1Hz;

[0023] Microbial sensor: initial detection frequency 0.5Hz;

[0024] During the monitoring cycle, the vibration sensor first collects the pipeline vibration frequency zdpl, vibration amplitude zdfd and vibration acceleration sd. After dimensionless processing, the vibration rate V is generated using the following formula:

[0025] ;

[0026] Where, represents pi, expressed as 3.14159;

[0027] Then calculate the ratio of the vibration velocity V and the vibration acceleration, and generate the pipeline vibration coefficient K using the following formula:

[0028]

[0029] The stress value wbyl of the outer wall of the pipeline, the displacement value wyz of the outer wall of the pipeline, the microbial concentration value wsnd per unit area of ​​the outer wall of the pipeline, the microbial pH value and the redox unit yhhy of the corrosion environment are collected through the stress sensor, displacement sensor and microbial sensor;

[0030] When the pipeline vibration coefficient K exceeds the vibration threshold When an abnormal event occurs, the monitoring frequency of the stress sensor, displacement sensor and microbial sensor is increased to:

[0031] Stress sensor: detection frequency increased from 1Hz to 2Hz;

[0032] Displacement sensor: detection frequency increased from 1Hz to 2Hz;

[0033] Microbial sensor: Detection frequency increased from 0.5Hz to 1Hz.

[0034] Preferably, the step three includes:

[0035] S31, using a flow velocity sensor at a monitoring point in the middle of the second pipeline to obtain the flow velocity Ls of the medium inside the pipeline in real time, using a water content sensor to obtain the water content Lh in real time, and using a temperature sensor to obtain the inner wall temperature wd in real time;

[0036] S32, after performing linear normalization processing on the flow rate Ls, water content Lh and inner wall temperature wd of the medium inside the pipeline, the corresponding data values ​​are mapped in the interval Then, the first risk factor Fx1 is generated according to the following formula:

[0037]

[0038] Where, Indicates the flow rate value of the medium inside the pipeline during the i-th monitoring cycle; represents the water content in the i-th monitoring period, Indicates the internal temperature value of the pipeline during the i-th monitoring cycle, To measure the mean value of the flow rate of the medium inside the pipeline during each monitoring period, It is the average value of the water content inside the measured pipeline during the monitoring period; It is the average value of the internal temperature of the measured pipeline during the monitoring period; 、 and is the weight coefficient: and , , ,and ,in, , n is the number in the monitoring period, which is a positive integer greater than 1.

[0039] Preferably, the step three further comprises:

[0040] S33, comparing and evaluating the first risk coefficient Fx1 with a first risk threshold;

[0041] If the first risk coefficient Fx1 is higher than the first risk threshold, it indicates that there are potential risks and abnormalities in the pipeline, indicating abnormal flow velocity, water content or inner wall temperature of the pipeline. This indirectly determines that corrosion, cracks or damage on the inner wall of the oil and gas pipeline have caused abnormal changes in medium flow velocity, water content or temperature. The current area is screened as a defective area and a first warning instruction is generated.

[0042] When the first risk coefficient Fx1 is not higher than the first risk threshold, it indicates that there is no abnormality in the pipeline and the current area is selected as a qualified area;

[0043] S34: After screening, the defective areas are subjected to step 4 for secondary detailed monitoring.

[0044] Preferably, the electromagnetic eddy current density is calculated by Faraday's law of electromagnetic induction and Ohm's law :

[0045]

[0046]

[0047] Where, It represents the conductivity of the conductor, which describes the conductor's ability to conduct current; E represents the electric field strength, represents the time derivative operator, which represents the rate of change with respect to time. A represents the magnetic vector potential, which is an auxiliary quantity describing the magnetic field distribution and has a relationship with the magnetic field intensity B. ∇× is the curl operator, which represents the curl of the vector field and represents the curl of the magnetic field intensity B.

[0048] When the electromagnetic eddy current density Greater than the preset threshold , it means that there is a defect in the current risk area, and according to the electromagnetic eddy current density The distribution position of the defect is determined, the defect coordinate position and defect area are determined, and the first significant mark is made in the three-dimensional model of the oil and gas pipeline.

[0049] Preferably, the step five includes:

[0050] S51. Continuously obtain pipeline outer wall vibration, displacement, and microbial corrosion data collected from the third pipeline outer wall monitoring point in each area, including: pipeline outer wall stress value wbyl, pipeline outer wall displacement value wyz, pipeline outer wall microbial concentration value wsnd per unit area, microbial pH value, corrosion environment redox unit yhhy, and pipeline vibration coefficient K. After dimensionless processing, generate the second risk factor Fx2 using the following formula:

[0051]

[0052] Where BZ1 represents the stress threshold of the pipeline outer wall, BZ2 represents the displacement threshold of the pipeline outer wall, BZ3 represents the product threshold of the microbial concentration value per unit area of ​​the pipeline outer wall and the redox unit of the corrosive environment, and BZ4 represents the microbial pH value threshold. represents the vibration threshold, , , , , ,and , d1, d2, d3, d4 and d5 are weight values, and their specific values ​​are adjusted by the user is the first constant correction coefficient;

[0053] S52: Compare and evaluate the second risk coefficient Fx2 with a second risk threshold to obtain a second evaluation result, including:

[0054] If the second risk factor Fx2 is higher than the second risk threshold, it indicates that the pipeline outer wall environment is abnormal, and a second strategy is generated, including: prioritizing maintenance and repair work in areas with abnormal pipeline outer wall environment, taking cleaning measures, including removing dirt and disinfection and sterilization; applying coating protection to the pipeline outer wall affected by corrosion or environmental factors, and structurally reinforcing the pipeline outer wall areas affected by stress or vibration;

[0055] If the second risk coefficient Fx2 is not higher than the second risk threshold, it indicates that the environment of the pipeline outer wall is normal.

[0056] Preferably, the step six includes:

[0057] S61. Set a fourth connection monitoring point at the connection between each area and the adjacent area pipeline, install an ultrasonic sensor, a first flow velocity sensor, and a second flow velocity sensor at the fourth connection monitoring point, and obtain the deposit thickness djwhd and crack depth lwsd at the pipeline connection through the ultrasonic sensor;

[0058] S62. Install a first flow velocity sensor 5cm-15cm from the end of each zone, and a second flow velocity sensor 5cm-15cm from the connection between adjacent zones. Obtain the first flow velocity dyl1 of each zone and the second flow velocity dyl2 of the second zone. Calculate the flow velocity difference slcz by differential calculation: slcz = dyl1 - dyl2. Calculating the flow velocity difference slcz means that if there is an abnormality at the pipe connection, including blockage or leakage, the flow velocity difference sllz will change.

[0059] S63, after dimensionless processing of the deposit thickness djwhd, the crack depth lwsd and the flow velocity difference slcz, the third risk factor Fx3 is generated by the following formula:

[0060]

[0061] Where BZ5 represents the thickness threshold of the deposit at the pipeline connection, BZ6 represents the crack depth threshold of the pipeline connection, and BZ7 represents the flow velocity difference threshold. , , ,and , d6, d7 and d8 are weight values, and their specific values ​​are adjusted by the user is the second constant correction coefficient;

[0062] S64, and comparing and evaluating the third risk coefficient Fx3 with the third risk threshold to obtain a third evaluation result, including:

[0063] If the third risk factor Fx3 is higher than the third risk threshold, it indicates that there is an abnormal defect at the pipeline connection, and a third strategy is generated, including: prioritizing emergency repair measures in the area of ​​the pipeline connection, including clearing deposits and repairing cracks, and increasing the monitoring frequency of the fourth connection monitoring point to track changes in the situation at the pipeline connection;

[0064] If the third risk coefficient Fx3 is not higher than the third risk threshold, it indicates that the pipeline connection is normal.

[0065] Preferably, for each region for generating the second strategy and the third strategy, the second difference between the second risk coefficient Fx2 and the second risk threshold, as well as the third difference between the third risk coefficient Fx3 and the third risk threshold are calculated, and each region is prioritized from high to low according to the second difference and the third difference to execute the second strategy or the third strategy.

[0066] An electromagnetic monitoring system for oil and gas pipeline defects, comprising:

[0067] The data collection and preprocessing module collects geographic, engineering, and design data related to oil and gas pipelines, performs preprocessing, and uses CAD software to create a three-dimensional model of the oil and gas pipeline, including the pipeline's topological network structure and the pipeline's surrounding environment;

[0068] The topological network structure analysis module divides the three-dimensional model of the oil and gas pipeline into a topological network structure, establishes a topological relationship diagram between regions, sets monitoring points in each region, and sets connection monitoring points at the connection points;

[0069] The internal medium flow parameter monitoring module monitors the flow rate Ls, water content Lh and inner wall temperature wd of the pipeline in real time, calculates the first risk coefficient Fx1 based on the monitoring data, evaluates and screens the risk area, and sends the first early warning instruction;

[0070] The electromagnetic eddy current density calculation and evaluation module calculates the electromagnetic eddy current density using Faraday's law of electromagnetic induction and Ohm's law when screening the current risk area. , assess the current risk area situation and determine the defect coordinate location;

[0071] The external environmental parameter monitoring module continuously obtains vibration, displacement, and microbial corrosion data collected from the outer wall monitoring points of each area, calculates the second risk factor Fx2, and performs an evaluation to obtain the second evaluation result and the second strategy;

[0072] The pipeline connection monitoring module sets connection monitoring points at the connection to monitor the thickness of the deposits and the depth of the cracks, calculates the third risk factor Fx3, and evaluates the third risk factor Fx3 to obtain a third evaluation result and a third strategy;

[0073] Abnormal event triggering and warning module, when the second risk factor Fx2 and the third risk factor Fx3 of a certain area exceed the corresponding thresholds, an abnormal event is triggered and the corresponding maintenance and repair strategies in the second strategy and the third strategy are generated;

[0074] The priority sorting and execution module prioritizes the generated second strategy and third strategy, and executes the strategy commands in descending order of priority according to the magnitude of the second difference and the third difference.

[0075] (3) Beneficial effects

[0076] The present invention provides an electromagnetic monitoring system and method for oil and gas pipeline defects, which has the following beneficial effects:

[0077] (1) The present invention performs preliminary screening through step three, which can effectively identify abnormal conditions of the medium flow rate, water content and inner wall temperature inside the pipeline. When an abnormality is found, the location of the inner wall defect is further determined by electromagnetic detection. This progressive screening method ensures accurate detection of defects on the inner wall of the pipeline. Compared with the traditional method of only performing electromagnetic detection on the inner wall of the pipeline, the present invention not only focuses on the defects of the inner wall of the pipeline, but also covers the monitoring of the environment and joints of the outer wall of the pipeline. By setting up multiple monitoring points, data such as outer wall vibration, displacement and microbial corrosion are systematically obtained, and sediment accumulation and fatigue cracks at the joints are monitored, thereby achieving comprehensive defect detection of oil and gas pipelines.

[0078] (2) When the pipeline vibration coefficient K exceeds the vibration threshold When an abnormal event is detected, the monitoring frequency of stress sensors, displacement sensors, and microbial sensors is increased, which helps to quickly identify and locate the problem and prevent potential damage from expanding. By increasing the frequency of sensor data collection, an abnormal situation in the pipeline can be responded to and handled more quickly.

[0079] (3) By calculating the first risk factor Fx1, collect the electromagnetic eddy current density Through comprehensive and accurate defect detection, the present invention reduces unnecessary downtime for maintenance, lowers maintenance costs, and improves pipeline operating efficiency. It can promptly detect and warn of potential safety hazards, provide targeted maintenance and repair strategies, and effectively improve the safety and reliability of oil and gas pipelines.

[0080] (4) For each region where the second and third strategies are generated, the second difference between the second risk factor Fx2 and the second risk threshold, as well as the third difference between the third risk factor Fx3 and the third risk threshold, are calculated. Prioritize each region from high to low according to the second and third differences, and implement the second or third strategy. Prioritizing high-risk regions can minimize the risk of pipeline accidents and ensure the safe operation of the pipeline system. Based on the ranking results of the second and third differences, maintenance and repair resources can be reasonably allocated, concentrating limited resources on resolving areas with higher risks. BRIEF DESCRIPTION OF THE DRAWINGS

[0081] Figure 1 This is a schematic flow chart of the steps of an electromagnetic monitoring method for oil and gas pipeline defects according to the present invention;

[0082] Figure 2 This is a block diagram and flow chart of an electromagnetic monitoring system for oil and gas pipeline defects according to the present invention. DETAILED DESCRIPTION

[0083] The following will clearly and completely describe the technical solutions in the embodiments of the present invention in conjunction with the accompanying drawings. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative efforts are within the scope of protection of the present invention.

[0084] Example 1

[0085] See also Figure 1 The present invention provides an electromagnetic monitoring method for oil and gas pipeline defects, comprising the following steps:

[0086] Step 1: Collect geographic, engineering, and design data related to the oil and gas pipeline, including the pipeline's topological structure and coordinate information, to establish a first visualization dataset. After preprocessing the first visualization dataset, use CAD software to create a three-dimensional model of the oil and gas pipeline. The three-dimensional model includes the pipeline's topological network structure and the pipeline's surrounding environment.

[0087] Step 2: Segment the three-dimensional model of the oil and gas pipeline into a topological network structure. For each area, determine its adjacent areas and connection relationships, establish a topological relationship diagram between regions, set a first pipeline monitoring point, a first pipeline inner wall electromagnetic monitoring point, a second pipeline middle monitoring point, and a third pipeline outer wall monitoring point in each area, and set a fourth connection monitoring point at the connection between each area and the adjacent area pipeline;

[0088] Step 3: Collect the flow rate Ls, water content Lh, and inner wall temperature wd of the medium inside the pipeline to construct a first risk coefficient Fx1. If the first risk coefficient Fx1 is higher than the first risk threshold, send a first warning instruction to the outside.

[0089] Step 4: When the first warning instruction is received, the electromagnetic monitoring information of the inner wall of the pipeline in the current risk area is collected through the electromagnetic eddy current detector, the electromagnetic field is numerically solved by the finite element method, and the electromagnetic eddy current density of the current risk area is constructed. After evaluation, the defect coordinates are determined and the first significant mark is made in the 3D model of the oil and gas pipeline;

[0090] Step 5: Continuously obtain the pipeline outer wall vibration, displacement, and microbial corrosion data collected from the third pipeline outer wall monitoring point in each area, construct a second risk factor Fx2, and evaluate the second risk factor Fx2 to obtain a second evaluation result and a second strategy;

[0091] Step 6: Collect sediment accumulation data and fatigue crack data at the connection through the fourth connection monitoring point, construct a third risk coefficient Fx3, and evaluate the third risk coefficient Fx3 to obtain a third evaluation result and a third strategy.

[0092] In this embodiment, the present invention performs preliminary screening through step three, which can effectively identify abnormal conditions of the medium flow rate, water content and inner wall temperature inside the pipeline. When an abnormality is found, the location of the inner wall defect is further determined by electromagnetic detection. This progressive screening method ensures the accurate detection of defects on the inner wall of the pipeline. Compared with the traditional method of only performing electromagnetic detection on the inner wall of the pipeline, the present invention not only focuses on the defects of the inner wall of the pipeline, but also covers the monitoring of the environment and joints of the outer wall of the pipeline. By setting up multiple monitoring points, data such as outer wall vibration, displacement and microbial corrosion are systematically obtained, and sediment accumulation and fatigue cracks at the joints are monitored to achieve comprehensive defect detection of oil and gas pipelines. Through multi-step risk factor assessment, the present invention can timely discover and warn potential safety hazards, provide targeted maintenance and repair strategies, and effectively improve the safety and reliability of oil and gas pipelines.

[0093] Example 2. This example is an explanation of Example 1. Specifically, the topological network structure includes pipeline segments, connectors, valves, brackets, and ancillary facilities. The three-dimensional model of the oil and gas pipeline obtained by modeling is presented as a visual image using visualization technology and graphic rendering methods. The visual image displays the internal and external structure of the pipeline, as well as various data information related to the pipeline.

[0094] In this example, CAD software and visualization technology are used to render the 3D model of the oil and gas pipeline into a visual image. This not only intuitively displays the internal and external structure of the pipeline, but also displays relevant data information, making the inspection results easier to analyze and understand, and improving data utilization efficiency.

[0095] Example 3: This example is explained in Example 1. Specifically, the first pipeline monitoring point includes a first pipeline inner wall electromagnetic monitoring point, a second pipeline middle monitoring point, and a third pipeline outer wall monitoring point.

[0096] The first pipeline inner wall electromagnetic monitoring point is used to install an electromagnetic eddy current detector and a magnetic resistance detector in the middle of the pipeline; and is used to monitor the integrity and defects of the pipeline inner wall.

[0097] The monitoring point in the middle of the second pipeline is used to install a temperature sensor, a water content sensor, and a flow rate sensor;

[0098] Install stress sensors, displacement sensors, vibration sensors and microbial sensors at the monitoring points on the outer wall of the third pipeline;

[0099] Stress sensor: initial monitoring frequency is 1Hz;

[0100] Displacement sensor: initial detection frequency 1Hz;

[0101] Vibration sensor: initial monitoring frequency 1Hz;

[0102] Microbial sensor: initial detection frequency 0.5Hz;

[0103] During the monitoring cycle, the vibration sensor first collects the pipeline vibration frequency zdpl, vibration amplitude zdfd and vibration acceleration sd. After dimensionless processing, the vibration rate V is generated using the following formula:

[0104] ;

[0105] Where, represents pi, expressed as 3.14159;

[0106] Then calculate the ratio of the vibration velocity V and the vibration acceleration, and generate the pipeline vibration coefficient K using the following formula:

[0107]

[0108] Assume that the vibration parameters of a pipeline are:

[0109] Vibration frequency (zdpl) = 50Hz;

[0110] Vibration amplitude (zdfd) = 0.01m;

[0111] Vibration acceleration value (sd) = 9.81m / s²; after dimensionless processing;

[0112] Step 1: Calculate the vibration velocity;

[0113] V=2π*50*0.01;

[0114] V=2*3.14159*50*0.01;

[0115] V ≈ 3.14 m / s;

[0116] Step 2: Calculate the vibration coefficient

[0117] K=3.14 / 9.8≈0.32;

[0118] Therefore, the vibration coefficient of the outer wall of the pipe is about 0.32.

[0119] The stress value wbyl of the outer wall of the pipeline, the displacement value wyz of the outer wall of the pipeline, the microbial concentration value wsnd per unit area of ​​the outer wall of the pipeline, the microbial pH value and the redox unit yhhy of the corrosion environment are collected through the stress sensor, displacement sensor and microbial sensor;

[0120] When the pipeline vibration coefficient K exceeds the vibration threshold When an abnormal event occurs, the monitoring frequency of the stress sensor, displacement sensor and microbial sensor is increased to:

[0121] Stress sensor: detection frequency increased from 1Hz to 2Hz;

[0122] Displacement sensor: detection frequency increased from 1Hz to 2Hz;

[0123] Microbial sensor: Detection frequency increased from 0.5Hz to 1Hz.

[0124] In this embodiment, increasing the sensor monitoring frequency after an abnormal event can capture changes in pipeline status more promptly and accurately. This provides more intensive data, helping to quickly identify and locate problems and prevent potential damage from escalating. Increasing the sensor data collection frequency allows for a more swift response and handling of pipeline abnormalities, shortening fault detection and repair time, thereby reducing downtime and maintenance costs. After frequency adjustment, the increased sensor data provided can be comprehensively analyzed to obtain more comprehensive information on pipeline health, assisting in long-term maintenance planning and optimizing operational strategies.

[0125] Example 4: This example is an explanation of Example 1. Specifically, step 3 includes:

[0126] S31, using a flow velocity sensor at a monitoring point in the middle of the second pipeline to obtain the flow velocity Ls of the medium inside the pipeline in real time, using a water content sensor to obtain the water content Lh in real time, and using a temperature sensor to obtain the inner wall temperature wd in real time;

[0127] S32, after performing linear normalization processing on the flow rate Ls, water content Lh and inner wall temperature wd of the medium inside the pipeline, the corresponding data values ​​are mapped in the interval Then, the first risk factor Fx1 is generated according to the following formula:

[0128]

[0129] Where, Indicates the flow rate value of the medium inside the pipeline during the i-th monitoring cycle; represents the water content in the i-th monitoring period, Indicates the internal temperature value of the pipeline during the i-th monitoring cycle, To measure the mean value of the flow rate of the medium inside the pipeline during each monitoring period, It is the average value of the water content inside the measured pipeline during the monitoring period; It is the average value of the internal temperature of the measured pipeline during the monitoring period; 、 and is the weight coefficient: and , , ,and ,in, , n is the number in the monitoring period, which is a positive integer greater than 1.

[0130] If cracks or holes appear in the pipeline, the medium may leak through the defects, causing the fluid pressure inside the pipeline to drop. Under the continuous action of equipment such as pumps, the flow rate in the pipeline may increase to compensate for the pressure loss. In this case, the local flow rate inside the pipeline may increase significantly, especially in the area near the defect. Pipeline defects can cause turbulence in the fluid flow, especially when the pipe wall is uneven or has protrusions. Fluctuations in flow rate will increase pressure fluctuations and mechanical stress inside the pipeline, which may further aggravate the expansion of defects. Pipeline defects (such as cracks or holes) make it easier for moisture from the external environment to enter the pipeline, especially in underground pipelines or humid environments. The increase in water content will aggravate the corrosion process inside the pipeline, especially electrochemical corrosion and microbial induced corrosion (MIC). Leakage at the defects will cause changes in the medium distribution inside the pipeline, and local moisture accumulation may form in certain areas. Leakage at the defects will cause changes in the flow characteristics of the medium in the pipeline, causing local temperature fluctuations. For example, changes in the flow velocity of the medium will affect convective heat transfer, thereby causing temperature changes;

[0131] S33, comparing and evaluating the first risk coefficient Fx1 with a first risk threshold;

[0132] If the first risk coefficient Fx1 is higher than the first risk threshold, it indicates that there are potential risks and abnormalities in the pipeline, indicating abnormal flow velocity, water content or inner wall temperature of the pipeline. This indirectly determines that corrosion, cracks or damage on the inner wall of the oil and gas pipeline have caused abnormal changes in medium flow velocity, water content or temperature. The current area is screened as a defective area and a first warning instruction is generated.

[0133] When the first risk coefficient Fx1 is not higher than the first risk threshold, it indicates that there is no abnormality in the pipeline and the current area is selected as a qualified area;

[0134] S34: After screening, the defective areas are subjected to step 4 for secondary detailed monitoring.

[0135] This embodiment provides a comprehensive method for assessing pipeline health by collecting and normalizing real-time data and calculating a first risk factor Fx1 based on the flow rate Ls, water content Lh, and inner wall temperature wd of the pipeline. Each parameter reflects a different aspect of the pipeline, and comprehensive analysis provides a more comprehensive understanding of the overall pipeline condition, enabling screening for defective areas. This allows monitoring and maintenance resources to be concentrated in high-risk areas, improving the efficiency and effectiveness of inspection and maintenance efforts.

[0136] Example 5: This example is an explanation of Example 1. Specifically, the electromagnetic eddy current density is calculated by Faraday's law of electromagnetic induction and Ohm's law. :

[0137]

[0138]

[0139] Where, It represents the conductivity of the conductor, which describes the conductor's ability to conduct current; E represents the electric field strength, represents the time derivative operator, which represents the rate of change with respect to time. A represents the magnetic vector potential, which is an auxiliary quantity describing the magnetic field distribution and has a relationship with the magnetic field intensity B. ∇× is the curl operator, which represents the curl of the vector field and represents the curl of the magnetic field intensity B.

[0140] When the electromagnetic eddy current density Greater than the preset threshold , it means that there is a defect in the current risk area, and according to the electromagnetic eddy current density The distribution position of the defect is determined, the defect coordinate position and defect area are determined, and the first significant mark is made in the three-dimensional model of the oil and gas pipeline.

[0141] In this embodiment, by calculating the electromagnetic eddy current density, the location of the defect in the pipeline can be accurately located. This helps to find and repair the defect in time and prevent accidents. Based on the distribution of the defects, the size and shape of the defects can be inferred and the area of ​​the defects can be further determined. This helps to assess the severity and scope of the defects.

[0142] Example 6: This example is an explanation of Example 1. Specifically, step 5 includes:

[0143] S51. Continuously obtain pipeline outer wall vibration, displacement, and microbial corrosion data collected from the third pipeline outer wall monitoring point in each area, including: pipeline outer wall stress value wbyl, pipeline outer wall displacement value wyz, pipeline outer wall microbial concentration value wsnd per unit area, microbial pH value, corrosion environment redox unit yhhy, and pipeline vibration coefficient K. After dimensionless processing, generate the second risk factor Fx2 using the following formula:

[0144]

[0145] Where BZ1 represents the stress threshold of the pipeline outer wall, BZ2 represents the displacement threshold of the pipeline outer wall, BZ3 represents the product threshold of the microbial concentration value per unit area of ​​the pipeline outer wall and the redox unit of the corrosive environment, and BZ4 represents the microbial pH value threshold. represents the vibration threshold, , , , , ,and , d1, d2, d3, d4 and d5 are weight values, and their specific values ​​are adjusted by the user is the first constant correction coefficient;

[0146] S52: Compare and evaluate the second risk coefficient Fx2 with a second risk threshold to obtain a second evaluation result, including:

[0147] If the second risk factor Fx2 is higher than the second risk threshold, it indicates that the pipeline outer wall environment is abnormal, and a second strategy is generated, including: prioritizing maintenance and repair work in areas with abnormal pipeline outer wall environment, taking cleaning measures, including removing dirt and disinfection and sterilization; applying coating protection to the pipeline outer wall affected by corrosion or environmental factors, and structurally reinforcing the pipeline outer wall areas affected by stress or vibration;

[0148] If the second risk coefficient Fx2 is not higher than the second risk threshold, it indicates that the environment of the pipeline outer wall is normal.

[0149] In this embodiment, step five covers the monitoring and assessment of the pipeline's outer wall environment, as well as the implementation of appropriate strategies for abnormal situations. By monitoring the second risk factor Fx2, abnormalities in the pipeline's outer wall environment can be promptly detected and corresponding maintenance strategies generated. This helps provide early warning, allowing for timely handling of abnormal situations and preventing further deterioration of the pipeline environment.

[0150] Example 7: This example is an explanation of Example 1. Specifically, step 6 includes:

[0151] S61. Set a fourth connection monitoring point at the connection between each area and the adjacent area pipeline, install an ultrasonic sensor, a first flow velocity sensor, and a second flow velocity sensor at the fourth connection monitoring point, and obtain the deposit thickness djwhd and crack depth lwsd at the pipeline connection through the ultrasonic sensor;

[0152] S62. Install a first flow velocity sensor 5cm-15cm from the end of each zone, and a second flow velocity sensor 5cm-15cm from the connection between adjacent zones. Obtain the first flow velocity dyl1 of each zone and the second flow velocity dyl2 of the second zone. Calculate the flow velocity difference slcz by differential calculation: slcz = dyl1 - dyl2. Calculating the flow velocity difference slcz means that if there is an abnormality at the pipe connection, including blockage or leakage, the flow velocity difference sllz will change.

[0153] S63, after dimensionless processing of the deposit thickness djwhd, the crack depth lwsd and the flow velocity difference slcz, the third risk factor Fx3 is generated by the following formula:

[0154]

[0155] Where BZ5 represents the thickness threshold of the deposit at the pipeline connection, BZ6 represents the crack depth threshold of the pipeline connection, and BZ7 represents the flow velocity difference threshold. , , ,and , d6, d7 and d8 are weight values, and their specific values ​​are adjusted by the user is the second constant correction coefficient;

[0156] S64, and comparing and evaluating the third risk coefficient Fx3 with the third risk threshold to obtain a third evaluation result, including:

[0157] If the third risk factor Fx3 is higher than the third risk threshold, it indicates that there is an abnormal defect at the pipeline connection, and a third strategy is generated, including: prioritizing emergency repair measures in the area of ​​the pipeline connection, including clearing deposits and repairing cracks, and increasing the monitoring frequency of the fourth connection monitoring point to track changes in the situation at the pipeline connection;

[0158] If the third risk coefficient Fx3 is not higher than the third risk threshold, it indicates that the pipeline connection is normal.

[0159] In this embodiment, step six involves monitoring and evaluating pipeline connections and implementing appropriate strategies for abnormal situations. Monitoring and evaluating pipeline connections allows for early detection of abnormalities, including accumulation of debris and cracks, to prevent them from becoming more severe. Based on the assessment results of the third risk factor Fx3, emergency repair measures can be implemented promptly to prevent pipeline connection problems from causing more serious consequences. For abnormal situations, increasing the monitoring frequency of the fourth connection monitoring point allows for more timely tracking of changes in pipeline connection conditions.

[0160] Example 8. This example is an explanation of Example 1. Specifically, for each area for generating the second strategy and the third strategy, the second difference between the second risk coefficient Fx2 and the second risk threshold, as well as the third difference between the third risk coefficient Fx3 and the third risk threshold are calculated and obtained. Each area is prioritized from high to low according to the second difference and the third difference to execute the second strategy or the third strategy.

[0161] In this embodiment, by calculating the second risk coefficient Fx2 and the third risk coefficient Fx3, the risk level of each area can be assessed and areas with abnormal conditions can be identified. Prioritizing high-risk areas can minimize the risk of pipeline accidents and ensure the safe operation of the pipeline system. Based on the sorting results of the second difference and the third difference, maintenance and repair resources can be reasonably allocated, and limited resources can be concentrated on resolving areas with higher risks. This can improve the efficiency of maintenance work and ensure the optimal utilization of resources. By prioritizing areas with higher risks, pipeline problems can be discovered and resolved in a timely manner to prevent further deterioration of the problems, thereby reducing maintenance costs. Timely maintenance and repair can prevent accidents caused by pipeline damage and avoid the huge losses caused by accidents. Executing the second strategy or the third strategy based on priority allows the maintenance team to work in an orderly manner and efficiently resolve pipeline problems.

[0162] Example 9, please refer to Figure 2 , an electromagnetic monitoring system for oil and gas pipeline defects, comprising,

[0163] The data collection and preprocessing module collects geographic, engineering, and design data related to oil and gas pipelines, performs preprocessing, and uses CAD software to create a three-dimensional model of the oil and gas pipeline, including the pipeline's topological network structure and the pipeline's surrounding environment;

[0164] The topological network structure analysis module divides the three-dimensional model of the oil and gas pipeline into a topological network structure, establishes a topological relationship diagram between regions, sets monitoring points in each region, and sets connection monitoring points at the connection points;

[0165] The internal medium flow parameter monitoring module monitors the flow rate Ls, water content Lh and inner wall temperature wd of the pipeline in real time, calculates the first risk coefficient Fx1 based on the monitoring data, evaluates and screens the risk area, and sends the first early warning instruction;

[0166] The electromagnetic eddy current density calculation and evaluation module calculates the electromagnetic eddy current density using Faraday's law of electromagnetic induction and Ohm's law when screening the current risk area. , assess the current risk area situation and determine the defect coordinate location;

[0167] The external environmental parameter monitoring module continuously obtains vibration, displacement, and microbial corrosion data collected from the outer wall monitoring points of each area, calculates the second risk factor Fx2, and performs an evaluation to obtain the second evaluation result and the second strategy;

[0168] The pipeline connection monitoring module sets connection monitoring points at the connection to monitor the thickness of the deposits and the depth of the cracks, calculates the third risk factor Fx3, and evaluates the third risk factor Fx3 to obtain a third evaluation result and a third strategy;

[0169] Abnormal event triggering and warning module, when the second risk factor Fx2 and the third risk factor Fx3 of a certain area exceed the corresponding thresholds, an abnormal event is triggered and the corresponding maintenance and repair strategies in the second strategy and the third strategy are generated;

[0170] The priority sorting and execution module prioritizes the generated second strategy and third strategy, and executes the strategy commands in descending order of priority according to the magnitude of the second difference and the third difference.

[0171] In this embodiment, the system integrates multiple monitoring and assessment modules to provide comprehensive protection for pipeline operation safety. First, the system acquires comprehensive pipeline-related data through the data collection and preprocessing module and creates a three-dimensional model using CAD software, providing an accurate foundation for subsequent analysis. Second, the system uses the topological network structure analysis module to perform topological segmentation on the pipeline, establish monitoring points, and monitor the flow parameters of the medium inside the pipeline in real time. Based on the monitoring data, the first risk factor Fx1 is calculated and the first early warning instruction is issued in a timely manner. In addition, the electromagnetic eddy current density calculation and assessment module accurately assesses risk areas, helping to prevent the occurrence of pipeline defects. The system also continuously monitors the external environmental parameters of the pipeline and calculates the second risk factor Fx2, promptly detecting abnormalities in the external pipeline environment and taking maintenance measures. In addition, the system monitors abnormalities at pipeline joints, assesses the third risk factor Fx3 at the joints, and implements targeted maintenance and repair strategies. Finally, the system prioritizes and executes maintenance strategies based on the priority of the risk factors, prioritizing high-risk areas and improving the efficiency of maintenance work. In summary, this monitoring system can effectively prevent pipeline accidents through comprehensive and real-time pipeline monitoring and evaluation, ensure the safety and stability of pipeline operations, and provide reliable protection for production and transportation in the oil and gas industry.

[0172] The threshold is set to facilitate comparison. The size of the threshold depends on the amount of sample data and the number of bases set by technicians in this field for each set of sample data; as long as it does not affect the proportional relationship between the parameter and the quantized value.

[0173] The above formulas are obtained by collecting a large amount of data and performing software simulation, and a formula close to the actual value is selected. The coefficients in the formula are set by those skilled in the art according to actual conditions. The above is only a preferred specific implementation method of the present invention, but the protection scope of the present invention is not limited to this. Any technician familiar with this technical field, within the technical scope disclosed by the present invention, can make equivalent replacements or changes based on the technical solution and inventive concept of the present invention, which should be covered by the protection scope of the present invention.

Claims

1. An electromagnetic monitoring method for oil and gas pipeline defects, characterized by: The following steps are included: Step 1: Collect geographic, engineering, and design data related to the oil and gas pipeline, including the pipeline's topological structure and coordinate information, to establish a first visualization dataset. After preprocessing the first visualization dataset, use CAD software to create a three-dimensional model of the oil and gas pipeline. The three-dimensional model includes the pipeline's topological network structure and the pipeline's surrounding environment. Step 2: Segment the three-dimensional model of the oil and gas pipeline into a topological network structure. For each area, determine its adjacent areas and connection relationships, establish a topological relationship diagram between regions, set a first pipeline monitoring point, a first pipeline inner wall electromagnetic monitoring point, a second pipeline middle monitoring point, and a third pipeline outer wall monitoring point in each area, and set a fourth connection monitoring point at the connection between each area and the adjacent area pipeline; Step 3: Collect the flow rate Ls, water content Lh, and inner wall temperature wd of the medium inside the pipeline to construct a first risk coefficient Fx1. If the first risk coefficient Fx1 is higher than the first risk threshold, send a first warning instruction to the outside. Step 4: When the first warning instruction is received, the electromagnetic monitoring information of the inner wall of the pipeline in the current risk area is collected through the electromagnetic eddy current detector, the electromagnetic field is numerically solved by the finite element method, and the electromagnetic eddy current density of the current risk area is constructed. After evaluation, the defect coordinates are determined and the first significant mark is made in the 3D model of the oil and gas pipeline; Step 5: Continuously obtain the pipeline outer wall vibration, displacement, and microbial corrosion data collected from the third pipeline outer wall monitoring point in each area, construct a second risk factor Fx2, and evaluate the second risk factor Fx2 to obtain a second evaluation result and a second strategy; Step 6: Collect sediment accumulation data and fatigue crack data at the connection through the fourth connection monitoring point, construct a third risk coefficient Fx3, and evaluate the third risk coefficient Fx3 to obtain a third evaluation result and a third strategy.

2. The electromagnetic monitoring method for oil and gas pipeline defects according to claim 1, characterized in that: The topological network structure includes pipeline segments, connectors, valves, supports, and ancillary facilities. Visualization technology and graphic rendering methods are used to present the modeled three-dimensional model of the oil and gas pipeline in a visual image. The visual image displays the internal and external structure of the pipeline, as well as various data information related to the pipeline.

3. The electromagnetic monitoring method for oil and gas pipeline defects according to claim 1, characterized in that: The first pipeline monitoring points include a first pipeline inner wall electromagnetic monitoring point, a second pipeline middle monitoring point and a third pipeline outer wall monitoring point; The first pipeline inner wall electromagnetic monitoring point is used to install an electromagnetic eddy current detector and a magnetic resistance detector in the middle of the pipeline; The monitoring point in the middle of the second pipeline is used to install a temperature sensor, a water content sensor, and a flow rate sensor; Install stress sensors, displacement sensors, vibration sensors and microbial sensors at the monitoring points on the outer wall of the third pipeline; Stress sensor: initial monitoring frequency is 1Hz; Displacement sensor: initial detection frequency 1Hz; Vibration sensor: initial monitoring frequency 1Hz; Microbial sensor: initial detection frequency 0.5Hz; During the monitoring cycle, the vibration sensor first collects the pipeline vibration frequency zdpl, vibration amplitude zdfd and vibration acceleration sd. After dimensionless processing, the vibration rate V is generated using the following formula: ； Where, represents pi, expressed as 3.14159; Then calculate the ratio of the vibration velocity V and the vibration acceleration, and generate the pipeline vibration coefficient K using the following formula: The stress value wbyl of the outer wall of the pipeline, the displacement value wyz of the outer wall of the pipeline, the microbial concentration value wsnd per unit area of ​​the outer wall of the pipeline, the microbial pH value and the redox unit yhhy of the corrosion environment are collected through the stress sensor, displacement sensor and microbial sensor; When the pipeline vibration coefficient K exceeds the vibration threshold When an abnormal event occurs, the monitoring frequency of the stress sensor, displacement sensor and microbial sensor is increased to: Stress sensor: detection frequency increased from 1Hz to 2Hz; Displacement sensor: detection frequency increased from 1Hz to 2Hz; Microbial sensor: Detection frequency increased from 0.5Hz to 1Hz.

4. The electromagnetic monitoring method for oil and gas pipeline defects according to claim 3, characterized in that: The step three includes: S31, using a flow velocity sensor at a monitoring point in the middle of the second pipeline to obtain the flow velocity Ls of the medium inside the pipeline in real time, using a water content sensor to obtain the water content Lh in real time, and using a temperature sensor to obtain the inner wall temperature wd in real time; S32, after performing linear normalization processing on the flow rate Ls, water content Lh and inner wall temperature wd of the medium inside the pipeline, the corresponding data values ​​are mapped in the interval Then, the first risk factor Fx1 is generated according to the following formula: ； Where, Indicates the flow rate value of the medium inside the pipeline during the i-th monitoring cycle; represents the water content in the i-th monitoring period, Indicates the internal temperature value of the pipeline during the i-th monitoring cycle, To measure the mean value of the flow velocity of the medium inside the pipeline during each monitoring period, It is the average value of the water content inside the measured pipeline during the monitoring period; It is the average value of the internal temperature of the measured pipeline during the monitoring period; 、 and is the weight coefficient: and , , ,and ,in, , n is the number in the monitoring period, which is a positive integer greater than 1.

5. The electromagnetic monitoring method for oil and gas pipeline defects according to claim 4, characterized in that: The step three also includes: S33, comparing and evaluating the first risk coefficient Fx1 with a first risk threshold; If the first risk coefficient Fx1 is higher than the first risk threshold, it indicates that there are potential risks and abnormalities in the pipeline, indicating abnormal flow velocity, water content or inner wall temperature of the pipeline. This indirectly determines that corrosion, cracks or damage on the inner wall of the oil and gas pipeline have caused abnormal changes in medium flow velocity, water content or temperature. The current area is screened as a defective area and a first warning instruction is generated. When the first risk coefficient Fx1 is not higher than the first risk threshold, it indicates that there is no abnormality in the pipeline and the current area is screened as a qualified area; S34: After screening, the defective areas are subjected to step 4 for secondary detailed monitoring.

6. The electromagnetic monitoring method for oil and gas pipeline defects according to claim 1, characterized in that: The electromagnetic eddy current density is calculated by Faraday's law of electromagnetic induction and Ohm's law : ； Where, It represents the conductivity of the conductor, which describes the conductor's ability to conduct current; E represents the electric field strength, represents the time derivative operator, which represents the rate of change with respect to time. A represents the magnetic vector potential, which is an auxiliary quantity describing the magnetic field distribution and has a relationship with the magnetic field intensity B. ∇× is the curl operator, which represents the curl of the vector field and represents the curl of the magnetic field intensity B. When the electromagnetic eddy current density Greater than the preset threshold , it means that there is a defect in the current risk area, and according to the electromagnetic eddy current density The distribution position of the defect is determined, the defect coordinate position and defect area are determined, and the first significant mark is made in the three-dimensional model of the oil and gas pipeline.

7. The electromagnetic monitoring method for oil and gas pipeline defects according to claim 6, characterized in that: The step five includes: S51. Continuously obtain pipeline outer wall vibration, displacement, and microbial corrosion data collected from the third pipeline outer wall monitoring point in each area, including: pipeline outer wall stress value wbyl, pipeline outer wall displacement value wyz, pipeline outer wall microbial concentration value wsnd per unit area, microbial pH value, corrosion environment redox unit yhhy, and pipeline vibration coefficient K. After dimensionless processing, generate the second risk factor Fx2 using the following formula: ； Where BZ1 represents the stress threshold of the pipeline outer wall, BZ2 represents the displacement threshold of the pipeline outer wall, BZ3 represents the product threshold of the microbial concentration value per unit area of ​​the pipeline outer wall and the redox unit of the corrosive environment, and BZ4 represents the microbial pH value threshold. represents the vibration threshold, , , , , ,and , d1, d2, d3, d4 and d5 are weight values, and their specific values ​​are adjusted by the user is the first constant correction coefficient; S52: Compare and evaluate the second risk coefficient Fx2 with a second risk threshold to obtain a second evaluation result, including: If the second risk factor Fx2 is higher than the second risk threshold, it indicates that the pipeline outer wall environment is abnormal, and a second strategy is generated, including: prioritizing maintenance and repair work in areas with abnormal pipeline outer wall environment, taking cleaning measures, including removing dirt and disinfection and sterilization; applying coating protection to the pipeline outer wall affected by corrosion or environmental factors, and structurally reinforcing the pipeline outer wall areas affected by stress or vibration; If the second risk coefficient Fx2 is not higher than the second risk threshold, it indicates that the environment of the pipeline outer wall is normal.

8. The electromagnetic monitoring method for oil and gas pipeline defects according to claim 1, characterized in that: The step six comprises: S61. Set a fourth connection monitoring point at the connection between each area and the adjacent area pipeline, install an ultrasonic sensor, a first flow velocity sensor, and a second flow velocity sensor at the fourth connection monitoring point, and obtain the deposit thickness djwhd and crack depth lwsd at the pipeline connection through the ultrasonic sensor; S62. Install a first flow velocity sensor 5cm-15cm from the end of each zone, and a second flow velocity sensor 5cm-15cm from the connection of each adjacent zone. Obtain the first flow velocity dyl1 of each zone and the second flow velocity dyl2 of the second zone. Calculate the flow velocity difference slcz by differential calculation: slcz = dyl1 - dyl2. Calculating the flow velocity difference slcz means that if there is an abnormality at the pipe connection, including blockage and leakage, the flow velocity difference slcz will change. S63, after dimensionless processing of the deposit thickness djwhd, the crack depth lwsd and the flow velocity difference slcz, the third risk factor Fx3 is generated by the following formula: ； Where BZ5 represents the thickness threshold of the deposit at the pipeline connection, BZ6 represents the crack depth threshold of the pipeline connection, and BZ7 represents the flow velocity difference threshold. , , ,and , d6, d7 and d8 are weight values, and their specific values ​​are adjusted by the user is the second constant correction coefficient; S64, and comparing and evaluating the third risk coefficient Fx3 with the third risk threshold to obtain a third evaluation result, including: If the third risk factor Fx3 is higher than the third risk threshold, it indicates that there is an abnormal defect at the pipeline connection, and a third strategy is generated, including: prioritizing emergency repair measures in the area of ​​the pipeline connection, including clearing deposits and repairing cracks, and increasing the monitoring frequency of the fourth connection monitoring point to track changes in the situation at the pipeline connection; If the third risk coefficient Fx3 is not higher than the third risk threshold, it indicates that the pipeline connection is normal.

9. The electromagnetic monitoring method for oil and gas pipeline defects according to claim 8, characterized in that: For each region where the second strategy and the third strategy are generated, the second difference between the second risk coefficient Fx2 and the second risk threshold, as well as the third difference between the third risk coefficient Fx3 and the third risk threshold, are calculated and obtained. Priority is then assigned to each region from high to low according to the second difference and the third difference to execute the second strategy or the third strategy.

10. An electromagnetic monitoring system for oil and gas pipeline defects, applied to the electromagnetic monitoring method for oil and gas pipeline defects according to any one of claims 1 to 9, characterized in that: include, The data collection and preprocessing module collects geographic, engineering, and design data related to oil and gas pipelines, performs preprocessing, and uses CAD software to create a three-dimensional model of the oil and gas pipeline, including the pipeline's topological network structure and the pipeline's surrounding environment; The topological network structure analysis module divides the three-dimensional model of the oil and gas pipeline into a topological network structure, establishes a topological relationship diagram between regions, sets monitoring points in each region, and sets connection monitoring points at the connection points; The internal medium flow parameter monitoring module monitors the flow rate Ls, water content Lh and inner wall temperature wd of the pipeline in real time, calculates the first risk coefficient Fx1 based on the monitoring data, evaluates and screens the risk area, and sends the first early warning instruction; The electromagnetic eddy current density calculation and evaluation module calculates the electromagnetic eddy current density using Faraday's law of electromagnetic induction and Ohm's law when screening the current risk area. , assess the current risk area situation and determine the defect coordinate location; The external environmental parameter monitoring module continuously obtains vibration, displacement, and microbial corrosion data collected from the outer wall monitoring points of each area, calculates the second risk factor Fx2, and performs an evaluation to obtain the second evaluation result and the second strategy; The pipeline connection monitoring module sets connection monitoring points at the connection to monitor the thickness of the deposits and the depth of the cracks, calculates the third risk factor Fx3, and evaluates the third risk factor Fx3 to obtain a third evaluation result and a third strategy; Abnormal event triggering and warning module, when the second risk factor Fx2 and the third risk factor Fx3 of a certain area exceed the corresponding thresholds, an abnormal event is triggered and the corresponding maintenance and repair strategies in the second strategy and the third strategy are generated; The priority sorting and execution module prioritizes the generated second strategy and third strategy, and executes the strategy commands in descending order of priority according to the magnitude of the second difference and the third difference.

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