Method for monitoring long-distance transmission state of power transmission line

Abstract

The invention specifically relates to a long-distance transmission state monitoring method for a power transmission line, and relates to the technical field of power transmission line monitoring. Monitoring in the air; monitoring the ground; combined analysis: comprehensively processing the insulator evaluation coefficient, the electric wire evaluation coefficient and the ground evaluation coefficient to obtain a risk evaluation coefficient; and state judgment. According to the invention, the influence of natural environmental factors on the power transmission line is comprehensively considered, the environmental information is obtained through various sensors and monitoring equipment, and the insulator, the wire and the ground environment of the power transmission line are comprehensively monitored, so that main influence factors in the operation process of the power transmission line can be covered; the state of the power transmission line is monitored in all directions; through detailed analysis of various parameters of the insulator, the wire and the ground environment, the actual operation state and the potential risk of the power transmission line can be accurately reflected, and the accuracy and the reliability of evaluation are improved.

Description

Technical Field

[0001] The present invention relates to the technical field of power transmission line monitoring, and in particular to a method for monitoring the long-distance transmission status of a power transmission line. Background Art

[0002] With the rapid development of the power industry, the scale of transmission lines continues to expand, and long-distance power transmission has become a crucial means of ensuring power supply. However, during operation, transmission lines are subject to various natural environmental factors such as rain, snow, hail, strong winds, and lightning. Furthermore, components such as the line's insulators, wires, and foundations can age and deteriorate over time. Failures in transmission lines not only disrupt the normal power supply but can also lead to serious safety incidents, resulting in significant economic losses and social impacts.

[0003] At present, although there are some transmission line monitoring methods, most of them have problems such as incomplete monitoring, low accuracy, and inability to provide timely warnings.

[0004] For example, existing environmental monitoring methods may not be able to accurately determine the impact of severe weather on transmission lines, making it difficult to trigger targeted monitoring in advance; for the status monitoring of insulators and wires, there is a lack of effective multi-parameter comprehensive evaluation methods, which cannot accurately reflect their actual status; ground environmental monitoring is often not detailed enough and cannot promptly detect potential problems with tower foundations.

[0005] Therefore, a method for monitoring the long-distance transmission status of a transmission line is needed to address the above-mentioned problems. Summary of the Invention

[0006] The purpose of the present invention is to solve the above problems and to propose a method for monitoring the long-distance transmission status of a power transmission line.

[0007] In order to achieve the above object, the present invention adopts the following technical solutions: A method for monitoring the long-distance transmission status of a power transmission line, comprising: Environmental judgment: Based on the trigger coefficient obtained from the analysis of natural environmental parameter information, the status monitoring of the transmission line is triggered, including aerial monitoring and ground monitoring of the transmission line; Aerial monitoring: Collect relevant information of the insulators and wires of the transmission lines, and analyze them to obtain the insulator evaluation coefficient and the wire evaluation coefficient; Ground monitoring: Processing the ground environment information of the transmission line to obtain the ground assessment coefficient; Combined analysis: The risk assessment coefficient is obtained by comprehensively processing the insulator assessment coefficient, wire assessment coefficient and ground assessment coefficient; Status judgment: Evaluate the risk level of the transmission line based on the risk assessment coefficient.

[0008] Preferably, the environment judgment specifically includes the following parts: Divide the transmission line into regions according to the preset area and obtain the natural environment parameter information of each region; the natural environment parameter information includes: rain, snow, hail, wind, and lightning; Acquire monitoring values of various parameters at preset time intervals, preset allowable ranges for various parameters, compare the monitoring values of various parameters with their corresponding allowable ranges, mark parameters that are not within the allowable ranges as deviating parameters, and calculate the difference between the monitoring values of the deviating parameters and the value corresponding to the maximum allowable range in the allowable range of the parameter to obtain a deviation difference; The trigger coefficient is obtained by weighting the deviation difference of each parameter; A trigger coefficient threshold is preset, and the trigger coefficient is compared with the preset trigger coefficient threshold. If the trigger coefficient is greater than the preset trigger coefficient threshold, the status monitoring of the transmission line is triggered.

[0009] Preferably, the process of obtaining the insulator evaluation coefficient includes: Extracting an image of the initial position of the insulator when it is put into use, wherein the image includes the insulator mark and the pole tower mark; connecting the mark points of the insulator mark and the pole tower with a straight line, recording the straight line as the calibration line, and obtaining the size of the calibration line as the calibration line length; When the state monitoring of the transmission line is triggered, an insulator comparison image at that time is obtained, and a calibration line is extracted from the insulator comparison image; Overlap one end of the calibration line in the insulator comparison image with one end of the corresponding calibration line in the insulator initial position image, and also overlap the insulators in the two images; obtain the angle formed by the two calibration lines and record it as the deviation; When the insulator marking point in the insulator comparison image cannot be identified, the insulator initial position image and the insulator comparison image are overlapped, and the area of the insulator comparison image is divided by the area of the insulator initial position image to obtain the comparison degree; Calculating the calibration line lengths in the insulator comparison image and the insulator initial position image respectively, and performing difference calculation on the calibration line lengths in the insulator comparison image and the insulator initial position image to obtain the line length deviation; Acquire images of the insulator at various angles, pre-process the images, construct a three-dimensional image of the insulator, extract damage and crack features from the images at various angles, and mark the areas where the damage features and crack features are located to obtain the damage area and crack area; Mark the contours of each damaged area and crack area in the 3D image of the insulator; Arrange the damaged areas and crack areas in descending order according to their sizes, and extract the largest damaged area and the largest crack area; obtain the two ends of the crack corresponding to the largest crack area, and the approximate center point of the largest damaged area; Connect the two ends of the crack corresponding to the largest crack area and the approximate center point of the largest damaged area with a straight line to form a triangular model. Calculate the area of the triangular model and record it as the rupture value. The insulator evaluation coefficient is obtained by comprehensively processing the deviation degree, comparison degree, line length deviation and rupture value.

[0010] Preferably, the process of obtaining the wire evaluation coefficient includes: Acquire image information of the wires at preset time intervals, and project the wire images acquired at each time interval onto the same horizontal plane; and use the projection of the wire that remains in the same position for a preset period of time on the horizontal plane as the reference wire; A preset number of connection points are arranged on the projection of the wire on the horizontal plane, and connecting lines perpendicular to the reference wire are drawn with the connection points as starting points. The obtained connecting lines are arranged in descending order according to the numerical value of the length, and the connecting line with the largest length is extracted as the swing line length; Obtain the swing line length corresponding to the projection of the wire on the plane at each time interval, and calculate the average of all the swing line lengths to obtain the swing average length; When the atmospheric temperature is within a preset range, the outline of the reference wire is obtained, and the distance between the outlines on both sides of the reference wire is obtained and recorded as the standard wire width; The projections of the wires on the horizontal plane obtained at each time interval are obtained respectively, and the line widths corresponding to the contours of the obtained projections of the wires are averaged to obtain the monitoring line width; Calculate the difference between the monitored line width and the standard line width to obtain the line width change value; The allowable fluctuation range of the line width change value is preset. If the line width change value is not within the allowable fluctuation range of the preset line width change value, the line width change value is recorded as an abnormal line width value; and at this time, the lowest point of the wire is triggered to monitor to obtain the fall value; The wire evaluation coefficient is obtained by weighted calculation of the swing moving average length, abnormal line width value and drop value.

[0011] Preferably, the process of obtaining the ground assessment coefficient includes: A preset number of monitoring poles are arranged in each divided area of the transmission line, and each monitoring pole is provided with a predetermined water level mark, and the water level value of each monitoring pole at an initial time is obtained, image information of the monitoring poles is obtained at preset time intervals, and the water level value is obtained based on the revealed water level mark; Obtain the water level values monitored by each monitoring pole in the area, and calculate the difference between each water level value and the initial water level value to obtain the height difference; The allowed range corresponding to the preset height difference is compared with the allowed range corresponding to the preset height difference, and the height difference that is not within the allowed range corresponding to the preset height difference is recorded as an abnormal height difference; Arrange the abnormal height differences in descending order according to their numerical values, and extract the three largest abnormal height differences; Draw circles with the monitoring pole positions corresponding to the three largest abnormal height differences as the center and the three largest abnormal height differences as the radius, and obtain three circles with the monitoring pole as the center; draw lines tangent to any two of the three circles, and obtain three circumtangents in total, and obtain a triangle formed by the three circumtangents, calculate the area of the triangle, and record it as the simulated water level difference value.

[0012] Preferably, the process of obtaining the ground assessment coefficient further includes: Obtaining image information of the initial position of the tower foundation surface, marking the cracks in the initial position image information and recording them as foundation cracks; and making reference marking points on the tower to determine the position of each foundation crack; Acquire image information of each foundation crack and a reference circle corresponding to each foundation crack at a preset time point; Draw a circle with a preset radius within the foundation crack to obtain a preset number of circles, obtain the overlap between each circle and the foundation crack, arrange them in descending order according to the size of the overlap, and mark the circle corresponding to the maximum overlap as the reference circle; The center of the reference circle at the initial position is obtained, and the center of the reference circle obtained at a preset time point after the moment corresponding to the initial position is obtained; the centers of the reference circles are connected with a straight line to obtain an offset, and an offset threshold is preset. If the offset is greater than the offset threshold, the offset is recorded as an offset loss; Obtain each offset vector and the center of the corresponding circle; connect the centers of the circles corresponding to each offset vector with a straight line to form a complete and closed figure, and the figure is the largest closed figure that can be formed; calculate the area of the closed figure and record it as the actual offset value; The ground assessment coefficient is obtained by comprehensively processing the simulated water level difference value and the actual offset value.

[0013] Preferably, the risk assessment coefficient is obtained by comprehensively processing the insulator assessment coefficient, the wire assessment coefficient and the ground assessment coefficient, specifically including: After normalizing the insulator assessment coefficient, wire assessment coefficient and ground assessment coefficient, the insulator assessment coefficient and wire assessment coefficient are used as the two right-angled sides of a right triangle respectively, and the remaining side is connected to obtain a complete right triangle. The right triangle is used as the base of a triangular pyramid, and the ground assessment coefficient is used as the height of the triangular pyramid to establish a triangular pyramid model. The volume of the triangular pyramid is calculated and recorded as the risk assessment coefficient.

[0014] Preferably, the risk level assessment of the transmission line based on the risk assessment coefficient includes assessing the risk level of the risk assessment coefficient of each area of the transmission line; Three groups of threshold value ranges are preset, and the value range of each group of threshold values corresponds to a risk level. The risk assessment coefficient is matched with the value range of the three groups of threshold values to obtain the risk level corresponding to the risk assessment coefficient, where the risk level includes normal, abnormal and emergency.

[0015] In summary, due to the adoption of the above technical solution, the beneficial effects of the present invention are: 1. The present invention comprehensively considers the impact of natural environmental factors on transmission lines, obtains environmental information through a variety of sensors and monitoring equipment, and comprehensively monitors the insulators, wires, and ground environment of the transmission lines. It can cover the main influencing factors during the operation of the transmission lines and realize all-round monitoring of the status of the transmission lines. By performing detailed analysis of various parameters of insulators, wires, and the ground environment, it can accurately reflect the actual operating status and potential risks of the transmission lines, thereby improving the accuracy and reliability of the assessment.

[0016] 2. The present invention can timely determine the risk level of the transmission line by comparing the risk assessment coefficient with the preset threshold. When the risk level reaches an abnormal or emergency state, an early warning can be issued in time so that the staff can take appropriate measures to deal with it, avoid the occurrence of faults, and ensure the safe and stable operation of the transmission line. BRIEF DESCRIPTION OF THE DRAWINGS

[0017] Further details, features and advantages of the present application are disclosed in the following description of exemplary embodiments in conjunction with the accompanying drawings, in which: Figure 1 Flow chart of the method of the present invention. DETAILED DESCRIPTION

[0018] Several embodiments of the present application will be described in more detail below with reference to the accompanying drawings so that those skilled in the art can implement the present application. The present application can be embodied in many different forms and for many different purposes and should not be limited to the embodiments described herein. These embodiments are provided to make the present application comprehensive and complete and to fully convey the scope of the present application to those skilled in the art. The embodiments do not limit the present application.

[0019] Unless otherwise defined, all terms (including technical and scientific terms) used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. It will be further understood that terms such as those defined in commonly used dictionaries should be interpreted as having a meaning consistent with their meaning in the relevant art and / or the context of this specification, and will not be interpreted in an idealized or overly formal sense unless expressly defined as such herein. Example

[0020] The specific implementation method is combined with the attached Figure 1 Provide detailed explanation.

[0021] Attachment Figure 1 A flow chart of a method for monitoring the long-distance transmission status of a power transmission line provided by an embodiment of the present invention shows the complete steps from environment judgment to status judgment.

[0022] In this embodiment, it includes: Environmental judgment: Based on the trigger coefficient obtained from the analysis of natural environmental parameter information, the status monitoring of the transmission line is triggered, including aerial monitoring and ground monitoring of the transmission line; Environmental assessment specifically includes the following parts: The transmission lines are divided into regions according to a preset area, and the natural environment parameter information of each region is obtained; the natural environment parameter information includes: rain, snow, hail, wind, and lightning.

[0023] Rain and snow sensors: Optical rain and snow sensors detect the presence of rain and snow particles by emitting and receiving light signals. When rain and snow particles enter the detection area, they scatter or block light, causing the received light signal to change, thereby determining the state of the rain and snow. Capacitive rain and snow sensors detect rain and snow by exploiting the effect of rain and snow on the dielectric between capacitor plates. When rain and snow contact the sensor's capacitor plates, the capacitance between the plates changes. By measuring this change in capacitance, the presence and intensity of rain and snow can be determined. There are also weighing rain and snow sensors that determine the amount of precipitation by measuring the weight of the collected rain and snow.

[0024] Weather radar: Doppler weather radar uses electromagnetic waves to emit into the air. These waves are reflected and scattered by precipitation particles such as hailstones. The radar receives the reflected signals and analyzes parameters such as signal strength, velocity, and spectral width to identify and track the development and evolution of hail clouds, as well as information such as the size, location, and movement of the hailstones. Generally speaking, hail clouds exhibit certain characteristics on radar echo patterns, such as strong echo areas, high echo tops, and significant three-body scattering.

[0025] Wind sensors: Common wind sensors include mechanical and electronic types. Mechanical wind sensors typically measure wind speed by rotating a cup or propeller in the wind, converting this rotation into an electrical signal through a mechanical transmission device. Electronic wind sensors measure wind speed based on principles such as ultrasound, heat transfer, or pressure differentials.

[0026] For example, ultrasonic wind speed sensors calculate wind speed by measuring the time difference between ultrasonic waves traveling through the air. Thermal wind speed sensors use the heat dissipation characteristics of a heating element in the airflow to measure wind speed. Wind direction is typically measured using a wind vane, which rotates as wind direction changes. The angle of rotation is converted into an electrical signal using a potentiometer or encoder, thereby determining wind direction.

[0027] Ground-based lightning location systems use electromagnetic radiation generated by lightning to pinpoint the location of lightning. When lightning strikes, it generates a powerful electric current, which radiates low-frequency electromagnetic waves. Multiple ground-based detection stations receive these electromagnetic wave signals. Based on the time difference between the signals reaching each station and the propagation speed of the electromagnetic waves, the lightning location can be calculated.

[0028] Acquire monitoring values of various parameters at preset time intervals, preset allowable ranges for various parameters, compare the monitoring values of various parameters with their corresponding allowable ranges, mark parameters that are not within the allowable ranges as deviating parameters, and calculate the difference between the monitoring values of the deviating parameters and the value corresponding to the maximum allowable range in the allowable range of the parameter to obtain a deviation difference; The trigger coefficient is obtained by weighting the deviation difference of each parameter; Preset the weight factor of each parameter respectively, multiply each parameter with its corresponding weight factor respectively, and sum them to obtain the trigger coefficient; A trigger coefficient threshold is preset, and the trigger coefficient is compared with the preset trigger coefficient threshold. If the trigger coefficient is greater than the preset trigger coefficient threshold, the status monitoring of the transmission line is triggered.

[0029] Aerial monitoring: Collect relevant information of the insulators and wires of the transmission lines, and analyze them to obtain the insulator evaluation coefficient and the wire evaluation coefficient.

[0030] The process of obtaining the insulator evaluation coefficient includes: The insulators are marked by laser marking, and the towers are also marked with corresponding positions. Images can be captured using drones or cameras installed at fixed points within the transmission line area. Laser marking is applied to insulators, and corresponding markings are placed on the towers. This provides clear reference points for subsequent image acquisition and analysis.

[0031] Use drones or cameras installed at fixed points within the transmission line area to capture images. Drones can flexibly capture insulator images from various angles, while fixed cameras can continuously monitor insulator condition from a specific location. Captured images should include insulator and tower markings for subsequent calibration and analysis.

[0032] Extracting an image of the initial position of the insulator when it is put into use, wherein the image includes the insulator mark and the pole tower mark; connecting the mark points of the insulator mark and the pole tower with a straight line, recording the straight line as the calibration line, and obtaining the size of the calibration line as the calibration line length; Extract an image of the insulator's initial position when it's in use. In this image, connect the insulator mark and the tower mark to form a calibration line, and obtain the length of this calibration line. This calibration line serves as the benchmark for subsequent comparisons, and its length is important reference data. When triggering the condition monitoring of the transmission line, the insulator comparison image at this time is obtained at the same position and lens angle as the initial position image of the insulator, and the calibration line is extracted from the insulator comparison image; Overlap one end of the calibration line in the insulator comparison image with one end of the corresponding calibration line in the insulator initial position image, and also overlap the insulators in the two images; obtain the angle formed by the two calibration lines and record it as the deviation; When the insulator marking point in the insulator comparison image cannot be identified, the insulator initial position image and the insulator comparison image are overlapped, and the area of the insulator comparison image is divided by the area of the insulator initial position image to obtain the comparison degree; When triggering transmission line condition monitoring, an insulator comparison image is acquired at the same position and lens angle as the initial position image. Calibration lines are also extracted from the comparison image. This ensures that image comparisons are performed under the same observation conditions, improving data accuracy and comparability.

[0033] Overlap one end of the calibration line in the comparison image with the corresponding end of the calibration line in the initial position image, and also overlay the insulators in both images. This way, the angle between the two calibration lines is obtained, which is the deviation. The deviation reflects the displacement of the insulator from its initial position during use; a larger angle indicates a more severe displacement. If the insulator markers in the insulator comparison image cannot be identified, the initial position image is overlaid with the comparison image. The comparison degree is calculated by dividing the area of the insulator comparison image by the area of the initial position image. The comparison degree measures the size change of the insulator in the image. The greater the area change, the greater the difference between the comparison degree and 1, which may indicate deformation or position change of the insulator. Calculating the calibration line lengths in the insulator comparison image and the insulator initial position image respectively, and performing difference calculation on the calibration line lengths in the insulator comparison image and the insulator initial position image to obtain the line length deviation; Acquire images of the insulator at various angles, pre-process the images, construct a three-dimensional image of the insulator, extract damage and crack features from the images at various angles, and mark the areas where the damage features and crack features are located to obtain the damage area and crack area; The construction of the three-dimensional image of the insulator based on images of the insulator at various angles is a direct reference to the existing technology, which mainly includes the steps of image acquisition, preprocessing, feature extraction and matching, and three-dimensional reconstruction, which will not be described in detail here; Mark the contours of each damaged area and crack area in the 3D image of the insulator; Arrange the damaged areas and crack areas in descending order according to their sizes, and extract the largest damaged area and the largest crack area; obtain the two ends of the crack corresponding to the largest crack area, and the approximate center point of the largest damaged area; Connect the two ends of the crack corresponding to the largest crack area and the approximate center point of the largest damaged area with a straight line to form a triangular model. Calculate the area of the triangular model and record it as the rupture value. The insulator evaluation coefficient is obtained by comprehensively processing the deviation degree, comparison degree, line length deviation and rupture value; After normalizing the deviation degree, comparison degree, line length deviation and rupture value, the product of the deviation degree and the comparison degree is used as one right-angled side of the triangle, the product of the line length deviation and the rupture value is used as the other right-angled side of the triangle, and the remaining side is connected to form a complete right-angled triangle. The area of the right-angled triangle is recorded as the insulator evaluation coefficient.

[0034] The process of obtaining the wire evaluation coefficient includes: Acquire image information of the wires at preset time intervals, and project the wire images acquired at each time interval onto the same horizontal plane; and use the projection of the wire that remains in the same position for a preset period of time on the horizontal plane as the reference wire; A preset number of connection points are arranged on the projection of the wire on the horizontal plane, and connecting lines perpendicular to the reference wire are drawn with the connection points as starting points. The obtained connecting lines are arranged in descending order according to the numerical value of the length, and the connecting line with the largest length is extracted as the swing line length; Obtain the swing line length corresponding to the projection of the wire on the plane at each time interval, and calculate the average of all the swing line lengths to obtain the swing average length; When the atmospheric temperature is within a preset range, the outline of the reference wire is obtained, and the distance between the outlines on both sides of the reference wire is obtained and recorded as the standard wire width; The outer wall of the reference wire contour obtained at this time is not covered with ice or snow, which can avoid the thickness change of the wire caused by ice or snow covering the reference wire; The projections of the wires on the horizontal plane obtained at each time interval are obtained respectively, and the line widths corresponding to the contours of the obtained projections of the wires are averaged to obtain the monitoring line width; Calculate the difference between the monitored line width and the standard line width to obtain the line width change value; The allowable fluctuation range of the line width change value is preset. If the line width change value is not within the allowable fluctuation range of the preset line width change value, the line width change value is recorded as an abnormal line width value; and at this time, the lowest point of the wire is triggered to monitor to obtain the fall value; Acquisition of the fall value includes: extracting an initial position image of the power lines in the area after the laying is completed, and acquiring position images of the power lines at preset time intervals, which are recorded as power line comparison position images; Extract the wire contours in the wire comparison position image and the wire initial position image respectively, and calculate the distance between the two wire contours, which is recorded as the contour distance difference; Obtain the wire contour distance difference corresponding to each time interval, and arrange the obtained contour distance differences in descending order according to their numerical values, and extract the largest contour distance difference, which is recorded as the fall value; The wire evaluation coefficient is obtained by weighting the swing average length, abnormal line width value and drop value; The weight factors of the swing average length, abnormal line width value and drop value are preset. The swing average length, abnormal line width value and drop value are multiplied by their corresponding weight factors respectively, and the sum is used to obtain the wire assessment coefficient.

[0035] Ground monitoring: Processing the ground environment information of the transmission line to obtain the ground assessment coefficient; The process of obtaining the ground assessment coefficient includes: A preset number of monitoring poles are arranged in each divided area of the transmission line, and each monitoring pole is provided with a predetermined water level mark and the water level value of each monitoring pole at an initial moment is obtained. Image information of the monitoring poles is obtained at preset time intervals, and the water level value is obtained based on the revealed water level mark. The monitoring poles can be arranged at the four corners and the center of the tower base; Obtain the water level values monitored by each monitoring pole in the area, and calculate the difference between each water level value and the initial water level value to obtain the height difference; The allowed range corresponding to the preset height difference is compared with the allowed range corresponding to the preset height difference, and the height difference that is not within the allowed range corresponding to the preset height difference is recorded as an abnormal height difference; Arrange the abnormal height differences in descending order according to their numerical values, and extract the three largest abnormal height differences; Draw circles with the monitoring pole positions corresponding to the three largest abnormal height differences as the center and the three largest abnormal height differences as the radius, and obtain three circles with the monitoring pole as the center; draw lines tangent to any two of the three circles, and obtain three circumtangents in total, and obtain a triangle formed by the three circumtangents, calculate the area of the triangle, and record it as the simulated water level difference value.

[0036] Obtaining image information of the initial position of the tower foundation surface, marking the cracks in the initial position image information and recording them as foundation cracks; and making reference marking points on the tower to determine the position of each foundation crack; Acquire image information of each foundation crack and a reference circle corresponding to each foundation crack at a preset time point; Draw a circle with a preset radius within the foundation crack to obtain a preset number of circles, obtain the overlap between each circle and the foundation crack, arrange them in descending order according to the size of the overlap, and mark the circle corresponding to the maximum overlap as the reference circle; The center of the reference circle at the initial position is obtained, and the center of the reference circle obtained at a preset time point after the moment corresponding to the initial position is obtained; the centers of the reference circles are connected with a straight line to obtain an offset, and an offset threshold is preset. If the offset is greater than the offset threshold, the offset is recorded as an offset loss; Obtain each offset vector and the center of the corresponding circle; connect the centers of the circles corresponding to each offset vector with straight lines to form a complete and closed figure, and this figure is the largest closed figure that can be formed; calculate the area of the closed figure and record it as the actual offset value.

[0037] The ground assessment coefficient is obtained by comprehensively processing the simulated water level difference value and the actual offset value; The simulated water level difference value and the actual offset value are marked as and The subsequent entry formula: , and obtain the ground assessment coefficient ;in and They are the maximum simulated value of water level difference and the maximum allowable value of actual deviation respectively; and are the weight factors corresponding to the simulated water level difference value and the actual offset value respectively.

[0038] Combined analysis: The risk assessment coefficient is obtained by comprehensively processing the insulator assessment coefficient, wire assessment coefficient and ground assessment coefficient; Specifically include: After normalizing the insulator assessment coefficient, wire assessment coefficient and ground assessment coefficient, the insulator assessment coefficient and wire assessment coefficient are used as the two right-angled sides of a right triangle respectively, and the remaining side is connected to obtain a complete right triangle. The right triangle is used as the base of a triangular pyramid, and the ground assessment coefficient is used as the height of the triangular pyramid to establish a triangular pyramid model. The volume of the triangular pyramid is calculated and recorded as the risk assessment coefficient.

[0039] Status judgment: Risk level assessment of transmission lines based on risk assessment coefficients; Conduct risk level assessment on the transmission line based on the risk assessment coefficient, including conducting risk level assessment on the risk assessment coefficient of each area of the transmission line; Three groups of threshold value ranges are preset, and the value range of each group of threshold values corresponds to a risk level. The risk assessment coefficient is matched with the value range of the three groups of threshold values to obtain the risk level corresponding to the risk assessment coefficient, where the risk level includes normal, abnormal and emergency.

[0040] When the risk level is normal: Maintain the existing monitoring frequency and method, and continuously collect data on environmental parameters, insulators, wires, and ground conditions of the transmission lines; When the risk level is abnormal: Increase monitoring frequency, increase the number of inspections of relevant areas, and use multiple monitoring methods for key monitoring. For example, for insulators and wires, increase the frequency of drone inspections; for the ground environment, more frequently check the water level of monitoring poles and cracks in tower foundations. Send real-time warning information to relevant operation and maintenance departments and personnel, informing them of abnormal conditions and potential risks of the transmission line, and reminding them to make emergency preparations so that they can respond quickly if the abnormal situation deteriorates further. When the risk level is emergency: While ensuring safety, swiftly shut down transmission lines with emergency risks to prevent the fault from escalating and causing more serious consequences, and to protect personnel and equipment. An on-site command center should be established to coordinate efforts and ensure efficient and orderly repairs. The command center should monitor the repair progress in real time, promptly resolve any issues encountered during the repair process, and maintain close communication with the power dispatching department to rationally schedule power outages and restorations.

[0041] 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 influencing weight factors and specific coefficient values in the formula are set by technical personnel in this field according to actual conditions, and can be adjusted and modified later.

[0042] The above embodiments can be implemented in whole or in part through software, hardware, firmware, or any other combination. When implemented using software, the above embodiments can be implemented in whole or in part in the form of a computer program product. The computer program product includes one or more computer instructions or computer programs. When the computer instructions or computer program are loaded or executed on a computer, the processes or functions described in the embodiments of the present application are generated in whole or in part. The computer can be a general-purpose computer, a special-purpose computer, a computer network, or other programmable device.

[0043] The computer instructions can be stored in a computer-readable storage medium or transmitted from one computer-readable storage medium to another computer-readable storage medium. For example, the computer instructions can be transmitted from one website, computer, server or data center to another website, computer, server or data center via wired or wireless (e.g., infrared, wireless, microwave, etc.) means.

[0044] The computer-readable storage medium can be any available medium that can be accessed by a computer, or a data storage device such as a server or data center that contains one or more available media. The available medium can be magnetic media, optical media, or semiconductor media. The semiconductor medium can be a solid-state drive.

[0045] It should be understood that the term "and / or" as used herein simply describes a relationship between associated objects, indicating that three possible relationships exist. For example, "A and / or B" can represent: A alone, A and B together, or B alone. A and B can be singular or plural. Furthermore, the character " / " as used herein generally indicates an "or" relationship between the associated objects, but it may also indicate an "and / or" relationship. For specific understanding, please refer to the context.

[0046] In the several embodiments provided in this application, it should be understood that the disclosed systems, devices, and methods can be implemented in other ways.

[0047] For example, the device embodiments described above are merely illustrative. For example, the division of units described herein is merely a logical functional division. Actual implementations may employ alternative divisions, such as combining or integrating multiple units or components into another system, or omitting or disabling certain features. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be through an interface, or indirect coupling or communication connection between devices or units, which may be electrical, mechanical, or other.

[0048] 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 these units may be selected to achieve the purpose of this embodiment according to actual needs.

[0049] In addition, each functional unit in each embodiment of the present application may be integrated into one processing unit, or each unit may exist physically separately, or two or more units may be integrated into one unit.

[0050] If the functions are implemented in the form of software functional units and sold or used as independent products, they can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present application, or the part that contributes to the prior art, or part of the technical solution, can be embodied in the form of a software product. The computer software product is stored in a storage medium and includes a number of instructions for enabling a computer device (which can be a personal computer, server, or network device, etc.) to perform all or part of the steps of the method described in each embodiment of the present application.

[0051] The aforementioned storage media include: USB flash drives, mobile hard disks, read-only memories, random access memories, magnetic disks, optical disks, and other media that can store program codes.

[0052] The above description of the embodiments is intended to enable one skilled in the art to implement or use the present invention. Various modifications to these embodiments will be readily apparent to those skilled in the art, and the general principles defined herein may be implemented in other embodiments without departing from the spirit or scope of the present invention. Therefore, the present invention is not limited to the embodiments shown herein but is intended to conform to the widest scope consistent with the principles and novel features disclosed herein.

Claims

1. A method for monitoring the long-distance transmission status of a power transmission line, characterized in that: include: Environmental judgment: Based on the trigger coefficient obtained from the analysis of natural environmental parameter information, the status monitoring of the transmission line is triggered, including aerial monitoring and ground monitoring of the transmission line; Aerial monitoring: Collect relevant information of the insulators and wires of the transmission lines, and analyze them to obtain the insulator evaluation coefficient and the wire evaluation coefficient; Ground monitoring: Processing the ground environment information of the transmission line to obtain the ground assessment coefficient; Combined analysis: The risk assessment coefficient is obtained by comprehensively processing the insulator assessment coefficient, wire assessment coefficient and ground assessment coefficient; Status judgment: Evaluate the risk level of the transmission line based on the risk assessment coefficient.

2. A method for monitoring the long-distance transmission status of a power transmission line according to claim 1, characterized in that: Environmental assessment specifically includes the following parts: Divide the transmission line into regions according to the preset area and obtain the natural environment parameter information of each region; Natural environment parameter information includes: rain, snow, hail, wind, and lightning; Acquire monitoring values of various parameters at preset time intervals, preset allowable ranges for various parameters, compare the monitoring values of various parameters with their corresponding allowable ranges, mark parameters that are not within the allowable ranges as deviating parameters, and calculate the difference between the monitoring values of the deviating parameters and the value corresponding to the maximum allowable range in the allowable range of the parameter to obtain a deviation difference; The trigger coefficient is obtained by weighting the deviation difference of each parameter; A trigger coefficient threshold is preset, and the trigger coefficient is compared with the preset trigger coefficient threshold. If the trigger coefficient is greater than the preset trigger coefficient threshold, the status monitoring of the transmission line is triggered.

3. A method for monitoring the long-distance transmission status of a power transmission line according to claim 2, characterized in that: The process of obtaining the insulator evaluation coefficient includes: Extracting an image of the initial position of the insulator when it is put into use, wherein the image includes the insulator mark and the pole tower mark; connecting the mark points of the insulator mark and the pole tower with a straight line, recording the straight line as the calibration line, and obtaining the size of the calibration line as the calibration line length; When the state monitoring of the transmission line is triggered, an insulator comparison image at that time is obtained, and a calibration line is extracted from the insulator comparison image; Overlap one end of the calibration line in the insulator comparison image with one end of the corresponding calibration line in the insulator initial position image, and also overlap the insulators in the two images; obtain the angle formed by the two calibration lines and record it as the deviation; When the insulator marking point in the insulator comparison image cannot be identified, the insulator initial position image and the insulator comparison image are overlapped, and the area of the insulator comparison image is divided by the area of the insulator initial position image to obtain the comparison degree; Calculating the calibration line lengths in the insulator comparison image and the insulator initial position image respectively, and performing difference calculation on the calibration line lengths in the insulator comparison image and the insulator initial position image to obtain the line length deviation; Acquire images of the insulator at various angles, pre-process the images, construct a three-dimensional image of the insulator, extract damage and crack features from the images at various angles, and mark the areas where the damage features and crack features are located to obtain the damage area and crack area; Mark the contours of each damaged area and crack area in the 3D image of the insulator; Arrange the damaged areas and crack areas in descending order according to their sizes, and extract the largest damaged area and the largest crack area; obtain the two ends of the crack corresponding to the largest crack area, and the approximate center point of the largest damaged area; Connect the two ends of the crack corresponding to the largest crack area and the approximate center point of the largest damaged area with a straight line to form a triangular model. Calculate the area of the triangular model and record it as the rupture value. The insulator evaluation coefficient is obtained by comprehensively processing the deviation degree, comparison degree, line length deviation and rupture value.

4. A method for monitoring the long-distance transmission status of a power transmission line according to claim 3, characterized in that: The process of obtaining the wire evaluation coefficient includes: Acquire image information of the wires at preset time intervals, and project the wire images acquired at each time interval onto the same horizontal plane; and use the projection of the wire that remains in the same position for a preset period of time on the horizontal plane as the reference wire; A preset number of connection points are arranged on the projection of the wire on the horizontal plane, and connecting lines perpendicular to the reference wire are drawn with the connection points as starting points. The obtained connecting lines are arranged in descending order according to the numerical value of the length, and the connecting line with the largest length is extracted as the swing line length; Obtain the swing line length corresponding to the projection of the wire on the plane at each time interval, and calculate the average of all the swing line lengths to obtain the swing average length; When the atmospheric temperature is within a preset range, the outline of the reference wire is obtained, and the distance between the outlines on both sides of the reference wire is obtained and recorded as the standard wire width; The projections of the wires on the horizontal plane obtained at each time interval are obtained respectively, and the line widths corresponding to the contours of the obtained projections of the wires are averaged to obtain the monitoring line width; Calculate the difference between the monitored line width and the standard line width to obtain the line width change value; The allowable fluctuation range of the line width change value is preset. If the line width change value is not within the allowable fluctuation range of the preset line width change value, the line width change value is recorded as an abnormal line width value; and at this time, the lowest point of the wire is triggered to monitor to obtain the fall value; The wire evaluation coefficient is obtained by weighted calculation of the swing moving average length, abnormal line width value and drop value.

5. A method for monitoring the long-distance transmission status of a power transmission line according to claim 4, characterized in that: The process of obtaining the ground assessment coefficient includes: A preset number of monitoring poles are arranged in each divided area of the transmission line, and each monitoring pole is provided with a predetermined water level mark, and the water level value of each monitoring pole at an initial time is obtained, image information of the monitoring poles is obtained at preset time intervals, and the water level value is obtained based on the revealed water level mark; Obtain the water level values monitored by each monitoring pole in the area, and calculate the difference between each water level value and the initial water level value to obtain the height difference; The allowed range corresponding to the preset height difference is compared with the allowed range corresponding to the preset height difference, and the height difference that is not within the allowed range corresponding to the preset height difference is recorded as an abnormal height difference; Arrange the abnormal height differences in descending order according to their numerical values, and extract the three largest abnormal height differences; Draw circles with the monitoring pole positions corresponding to the three largest abnormal height differences as the center and the three largest abnormal height differences as the radius, and obtain three circles with the monitoring pole as the center; draw lines tangent to any two of the three circles, and obtain three circumtangents in total, and obtain a triangle formed by the three circumtangents, calculate the area of the triangle, and record it as the simulated water level difference value.

6. A method for monitoring the long-distance transmission status of a power transmission line according to claim 5, characterized in that: The process of obtaining the ground assessment coefficient also includes: Obtaining image information of the initial position of the tower foundation surface, marking the cracks in the initial position image information and recording them as foundation cracks; and making reference marking points on the tower to determine the position of each foundation crack; Acquire image information of each foundation crack and a reference circle corresponding to each foundation crack at a preset time point; Draw a circle with a preset radius within the foundation crack to obtain a preset number of circles, obtain the overlap between each circle and the foundation crack, arrange them in descending order according to the size of the overlap, and mark the circle corresponding to the maximum overlap as the reference circle; The center of the reference circle at the initial position is obtained, and the center of the reference circle obtained at a preset time point after the moment corresponding to the initial position is obtained; the centers of the reference circles are connected with a straight line to obtain an offset, and an offset threshold is preset. If the offset is greater than the offset threshold, the offset is recorded as an offset loss; Obtain each offset vector and the center of the corresponding circle; connect the centers of the circles corresponding to each offset vector with a straight line to form a complete and closed figure, and the figure is the largest closed figure that can be formed; calculate the area of the closed figure and record it as the actual offset value; The ground assessment coefficient is obtained by comprehensively processing the simulated water level difference value and the actual offset value.

7. A method for monitoring the long-distance transmission status of a power transmission line according to claim 6, characterized in that: The risk assessment coefficient is obtained by comprehensively processing the insulator assessment coefficient, wire assessment coefficient and ground assessment coefficient, which specifically includes: After normalizing the insulator assessment coefficient, wire assessment coefficient and ground assessment coefficient, the insulator assessment coefficient and wire assessment coefficient are used as the two right-angled sides of a right triangle respectively, and the remaining side is connected to obtain a complete right triangle. The right triangle is used as the base of a triangular pyramid, and the ground assessment coefficient is used as the height of the triangular pyramid to establish a triangular pyramid model. The volume of the triangular pyramid is calculated and recorded as the risk assessment coefficient.

8. A method for monitoring the long-distance transmission status of a power transmission line according to claim 7, characterized in that: Conduct risk level assessment on the transmission line based on the risk assessment coefficient, including conducting risk level assessment on the risk assessment coefficient of each area of the transmission line; Three groups of threshold value ranges are preset, and the value range of each group of threshold values corresponds to a risk level. The risk assessment coefficient is matched with the value range of the three groups of threshold values to obtain the risk level corresponding to the risk assessment coefficient, where the risk level includes normal, abnormal and emergency.

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