Panoramic sensing method and system for operation state of high-voltage device of power transmission line

Abstract

Disclosed in the present invention are a panoramic sensing method and system for an operation state of a high-voltage device of a power transmission line. The method comprises: acquiring first monitoring data, first detection data and first image data of a target device; on the basis of a preset degradation analysis method, performing degradation analysis on the first monitoring data, the first detection data, and the first image data to obtain a first degradation magnitude, a second degradation magnitude, and a third degradation magnitude; establishing a comprehensive evaluation model, and on the basis of the first degradation magnitude, the second degradation magnitude, and the third degradation magnitude, acquiring an operation state of the target device; and completing state sensing on the basis of the operation state of the target device. The method and the system can effectively reduce the risk of power outage caused by a device fault, and improve the operation reliability of power transmission lines. By means of the non-contact monitoring technology, the requirements on device insulation performance are reduced, and the maintenance cost and the operation risk are reduced. By means of the multi-parameter fusion technology, real-time monitoring of device states is realized, and the comprehensiveness and accuracy of monitoring and evaluation are improved.

Description

A panoramic perception method and system for the operating status of high-voltage equipment in power transmission lines Technical Field

[0001] This invention relates to the field of green and intelligent electrical equipment technology, and in particular to a method and system for panoramic perception of the operating status of high-voltage equipment in power transmission lines. Background Technology

[0002] In today's world, countries at different stages of economic development and with varying resource endowments share a common goal and face a common challenge: how to coordinate a secure and stable energy supply with a green and low-carbon transformation. New power systems possess the technological characteristics of gradually evolving from automation to digitalization and intelligence. Digital grids are new types of integrated social public facilities built with next-generation digital technologies. While improving the safety, reliability, greenness, and efficiency of the power system, they also guide the reshaping of power grid companies' production, management, and operation methods, promote the integration of the energy industry value chain, support the construction of an energy ecosystem, and serve the secure and stable energy supply and the green and low-carbon transformation.

[0003] The digital power grid technology system mainly consists of physical systems, information systems, and business systems. Based on the physical power grid, the digital power grid fully utilizes digital technologies and primarily includes physical systems composed of power grid equipment, business systems serving the operation of the physical systems, and information systems supporting the operation of both the physical and business systems. Among these, the business systems mainly cover the entire process of production and operation activities of power grid enterprises. In particular, the application of next-generation digital technologies to power grid operation and maintenance will improve the efficiency and quality of transmission line operation and maintenance. For example, by using IoT and edge computing technologies, intelligent sensing, measurement, and control equipment for conductors, surge arresters, insulators, etc., can be deployed to improve the monitoring effect of transmission lines and the level of panoramic perception of transmission line faults and analysis of operational trends.

[0004] Transmission lines are widely distributed and have complex corridors, making operation and maintenance extremely difficult; their operational status is also susceptible to weather, environmental factors, and natural disasters. The deterioration of high-voltage equipment's operational status often has a developmental phase. Monitoring the evolution trends of electrical and mechanical performance parameters can provide a comprehensive understanding of the operational status of high-voltage equipment on transmission lines and provide early warnings of potential faults. Previous methods, primarily based on single sensors, suffer from limitations in monitoring and evaluation, including being partial, incomplete, and delayed. Furthermore, contact-based measurement methods have high insulation performance requirements. Therefore, there is an urgent need for scientific research and application of multi-sensor monitoring, testing, and other status perception data, along with multi-parameter fusion technologies, to achieve comprehensive perception of the operational status. Summary of the Invention

[0005] The purpose of this section is to outline some aspects of embodiments of the present invention and to briefly describe some preferred embodiments. Simplifications or omissions may be made in this section, as well as in the abstract and title of this application, to avoid obscuring the purpose of these documents; however, such simplifications or omissions should not be construed as limiting the scope of the invention.

[0006] In view of the aforementioned existing problems, the present invention is proposed.

[0007] Therefore, the present invention provides a panoramic perception method and system for the operating status of high-voltage equipment in power transmission lines, which can solve the problems mentioned in the background art.

[0008] To solve the above-mentioned technical problems, the present invention provides the following technical solution:

[0009] In a first aspect, the present invention provides a method for panoramic perception of the operating status of high-voltage equipment in transmission lines, comprising:

[0010] Acquire the first monitoring data, first detection data, and first image data of the target device;

[0011] According to the preset degradation analysis method, the first monitoring data, the first detection data and the first image data are subjected to degradation analysis to obtain the first degradation amount, the second degradation amount and the third degradation amount;

[0012] A comprehensive evaluation model is established, and the operating status of the target equipment is obtained based on the first, second, and third degradation amounts.

[0013] Status perception is achieved based on the operating status of the target equipment.

[0014] As a preferred embodiment of the panoramic perception method for the operating status of high-voltage equipment in transmission lines described in this invention, the establishment of the comprehensive evaluation model includes:

[0015] The comprehensive evaluation model is any model whose output is a comprehensive score of the target equipment's operating status and whose input is the deterioration analysis result;

[0016] The degradation analysis results include at least one or more of the first degradation amount, the second degradation amount, or the third degradation amount.

[0017] As a preferred embodiment of the panoramic perception method for the operating status of high-voltage equipment in transmission lines according to the present invention, the step of performing degradation analysis on the first monitoring data, the first detection data, and the first image data according to a preset degradation analysis method includes:

[0018] The first image data is analyzed for degradation by using a preset first fusion recognition score algorithm to obtain the third degradation amount.

[0019] As a preferred embodiment of the panoramic perception method for the operating status of high-voltage equipment in transmission lines described in this invention, the comprehensive evaluation model includes:

[0020] The first, second, and third degradation levels are scored using a first-level rating system.

[0021] The first-level scoring results are then used to conduct a second-level scoring to obtain a comprehensive score of the target equipment's operating status.

[0022] As a preferred embodiment of the panoramic perception method for the operating status of high-voltage equipment in transmission lines described in this invention, the comprehensive score of the operating status of the target equipment includes several scoring intervals, and each scoring interval corresponds to a unique status level.

[0023] As a preferred embodiment of the panoramic perception method for the operating status of high-voltage equipment in transmission lines described in this invention, the first-level scoring includes:

[0024] Determine the percentage of samples in the state-aware data that have reached performance degradation conditions out of the total number of samples in the evaluation data.

[0025] Calculate the percentage of all state-sensing data samples that have reached the performance degradation condition out of all state-sensing data.

[0026] Determine the degree to which the state-aware data samples have degraded in performance;

[0027] The state-aware data includes a first degradation amount, a second degradation amount, and a third degradation amount.

[0028] As a preferred embodiment of the panoramic perception method for the operating status of high-voltage equipment in transmission lines described in this invention, the step of completing the status perception based on the operating status of the target equipment includes:

[0029] Determine the status level based on the operating status of the target equipment;

[0030] Send an alarm notification for this status level to the equipment operation and maintenance department.

[0031] Secondly, the present invention provides a panoramic perception system for the operating status of high-voltage equipment in transmission lines, comprising:

[0032] The data acquisition module is used to acquire the first monitoring data, the first detection data, and the first image data of the target device;

[0033] The degradation processing module is used to perform degradation analysis on the first monitoring data, the first detection data, and the first image data according to a preset degradation analysis method to obtain a first degradation amount, a second degradation amount, and a third degradation amount.

[0034] The model building module is used to build a comprehensive evaluation model and obtain the target equipment operating status based on the first degradation amount, the second degradation amount, and the third degradation amount.

[0035] The status awareness module is used to complete status awareness based on the operating status of the target device.

[0036] Thirdly, the present invention provides a computer device including a memory and a processor, wherein the memory stores a computer program, and the processor executes the computer program to implement the steps of the method described above.

[0037] Fourthly, the present invention provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the steps of the method described above.

[0038] Compared with existing technologies, the beneficial effects of this invention are as follows: This invention proposes a panoramic perception method and system for the operating status of high-voltage equipment in transmission lines. It acquires first monitoring data, first detection data, and first image data of the target equipment; performs degradation analysis on the first monitoring data, first detection data, and first image data according to a preset degradation analysis method to obtain a first degradation amount, a second degradation amount, and a third degradation amount; establishes a comprehensive evaluation model, and obtains the operating status of the target equipment based on the first degradation amount, the second degradation amount, and the third degradation amount; and completes status perception based on the operating status of the target equipment. Through the establishment of the comprehensive evaluation model, a comprehensive assessment of the operating status of high-voltage equipment in transmission lines can be achieved, thereby providing more accurate and timely maintenance decision support. This method and system can effectively reduce the risk of power outages caused by equipment failures and improve the operational reliability of transmission lines. The use of non-contact monitoring technology reduces the requirements for equipment insulation performance, lowering maintenance costs and operational risks. Through multi-parameter fusion technology, real-time monitoring of equipment status is achieved, improving the comprehensiveness and accuracy of monitoring and evaluation. Attached Figure Description

[0039] To more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings used in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort. Wherein:

[0040] Figure 1 is a flowchart of a panoramic perception method and system for the operating status of high-voltage equipment in transmission lines provided by an embodiment of the present invention;

[0041] Figure 2 is a detailed flowchart of a panoramic perception method and system for the operating status of high-voltage equipment in transmission lines according to an embodiment of the present invention.

[0042] Figure 3 is a neural network structure diagram of a panoramic perception method and system for the operating status of high-voltage equipment in transmission lines provided by an embodiment of the present invention;

[0043] Figure 4 is a system topology diagram of a panoramic perception method and system for the operating status of high-voltage equipment in transmission lines provided by an embodiment of the present invention.

[0044] Figure 5 is a schematic diagram of broadband voltage signal decoupling of a transmission line according to an embodiment of the present invention, which provides a panoramic perception method and system for the operating status of high-voltage equipment in transmission lines.

[0045] Figure 6 is an internal structure diagram of a computer device for a panoramic perception method and system for the operating status of high-voltage equipment in power transmission lines, provided in an embodiment of the present invention. Detailed Implementation

[0046] To make the above-mentioned objects, features, and advantages of the present invention more apparent and understandable, specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments of the present invention, and not all of them. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the protection scope of the present invention.

[0047] Example 1

[0048] Referring to Figures 1-6, the first embodiment of the present invention provides a panoramic perception method and system for the operating status of high-voltage equipment in transmission lines, including:

[0049] Existing technologies have some shortcomings. For example, traditional monitoring methods often rely on periodic manual inspections, which are not only time-consuming and labor-intensive but also difficult to achieve real-time monitoring of equipment status. Furthermore, due to the lack of effective data fusion and analysis methods, existing monitoring systems struggle to accurately assess the overall operating status of equipment, leading to untimely and inaccurate maintenance decisions.

[0050] This application provides a method that can effectively solve the problems mentioned above. The following will describe in detail how to realize the panoramic perception method for the operating status of high-voltage equipment in transmission lines, using multiple embodiments.

[0051] Figure 1 illustrates the flowchart of a panoramic perception method and system for the operating status of high-voltage equipment in transmission lines, including:

[0052] S101, acquire the first monitoring data, the first detection data, and the first image data of the target device;

[0053] In an optional embodiment, the first monitoring data can be online monitoring data of leakage current and temperature of transmission line insulators and voltage of overhead conductors collected by preset sensors, or vibration signals and sound signals of the transmission line. The first detection data can be manual inspection data of high-voltage equipment of transmission lines in the power grid management platform (asset domain) of the power grid enterprise, or electrical parameter data such as insulation resistance and contact resistance of equipment obtained from periodic inspections. The first image data can be visible light image recognition data of high-voltage equipment of transmission lines from the drone inspection and control platform of the power grid enterprise, or images of the surface condition of equipment taken by a high-definition camera, including but not limited to cracks, corrosion, dirt and other conditions of the equipment.

[0054] In this embodiment, the first monitoring data is the online monitoring data of leakage current and temperature of insulators and voltage of overhead conductors of transmission lines collected by sensors; the first detection data is the manual detection data of high-voltage equipment of transmission lines in the power grid management platform (asset domain) of the power grid enterprise; and the first image data is the visible light image recognition data of high-voltage equipment of transmission lines from the drone inspection and control platform of the power grid enterprise.

[0055] In an optional embodiment, the first monitoring data can be acquired by a sensor. The online monitoring data of leakage current of transmission line insulators can be acquired by a non-contact insulator leakage current monitoring sensor based on adaptive filtering and noise reduction; the online temperature monitoring data can be acquired by a non-contact composite insulator temperature monitoring sensor based on infrared thermal imaging; and the online monitoring data of overhead conductor voltage can be acquired by a non-contact overhead conductor broadband voltage monitoring sensor based on the principle of vector electric field coupling.

[0056] It should be noted that the relevant monitoring sensors for the first monitoring data adopt an automatic acquisition mode to reduce manual intervention. That is, the status quantities of high-voltage equipment of the transmission line are collected, processed and stored at predetermined time intervals, and the information is uploaded to the main station system located in the production command center of the provincial power grid enterprise.

[0057] In an optional embodiment, the manual detection data in the first detection data includes surge arrester tests, insulator live-line tests, conductor infrared thermography, and conductor sag measurements.

[0058] In an optional embodiment, the visible light inspection target objects in the first image data include overhead conductors, ground wires, surge arresters, insulators, and hardware.

[0059] It should be noted that acquiring the first monitoring data, first detection data, and first image data of the target equipment enables comprehensive monitoring of high-voltage equipment on transmission lines, allowing for the timely detection of potential faults and anomalies. Real-time monitoring allows for rapid response to changes in equipment status, effectively preventing power outages. Furthermore, this method can analyze historical data to predict potential equipment problems, providing a scientific basis for maintenance decisions and further improving the operational efficiency and reliability of transmission lines.

[0060] S102, perform degradation analysis on the first monitoring data, the first detection data and the first image data according to the preset degradation analysis method to obtain the first degradation amount, the second degradation amount and the third degradation amount;

[0061] In this embodiment of the application, the degradation analysis of the first monitoring data, the first detection data, and the first image data according to the preset degradation analysis method includes:

[0062] The first image data is analyzed for degradation by using a preset first fusion recognition score algorithm to obtain the third degradation amount.

[0063] In an optional embodiment, the first fusion recognition score algorithm may employ multimodal data fusion: this approach combines data from different sensors or multiple sources to improve the accuracy and robustness of recognition. For example, image data can be combined with sensor data to jointly analyze device degradation.

[0064] In an optional embodiment, the first fusion recognition score algorithm can also be a deep learning model: using deep learning techniques (such as convolutional neural networks (CNNs), recurrent neural networks (RNNs), etc.), features can be automatically extracted from large amounts of complex data and classified or regressed to predict the degree of degradation.

[0065] In an optional embodiment, the first fusion recognition score algorithm can also integrate learning: improving the overall model's performance by combining the predictions of multiple base models (such as decision trees, support vector machines, etc.). This method can be bagging, boosting, or stacking, etc.

[0066] It should be noted that regardless of the method used, the ultimate goal is to degrade the first image data to obtain a third degradation amount. Therefore, similar operations should all be within the protection scope of this application.

[0067] In this embodiment, the first fusion recognition score algorithm uses a set fusion recognition score to determine the relationship between real-time image information and historical experience values, thereby achieving the effect of degradation analysis.

[0068] Specifically, by fusing and analyzing the recognition results of global images of power transmission lines and local images of components captured by drones, the accuracy of the drone inspection image recognition results can be confirmed when the fused recognition score P is greater than the historical experience value.

[0069] In an optional embodiment, since the visible light inspection images captured by the UAV include global images of the transmission line and local images of overhead conductors, ground wires, surge arresters, insulators, and hardware components, a branch fusion method is proposed to simultaneously utilize both global and local information from the visible light inspection images and balance the roles of these two types of information in component image recognition. This method extracts component features at different scales. When the fused recognition score P is greater than a historical empirical value, the recognition results from both global and local images can be considered, thus ensuring recognition accuracy. The formula for calculating the recognition score P is as follows:

[0070]

[0071] Wherein, P1 refers to the recognition result of the global image input of the transmission line, P2 represents the recognition result of the local image input of the component, and μ and λ are the balance factors set to weigh different recognition results based on the prior values ​​of the positive samples trained by the model.

[0072] It should be noted that the proposed fusion recognition score algorithm aims to improve the accuracy of identifying the status of high-voltage equipment in transmission lines by comprehensively considering global and local image information. In practical applications, this algorithm can effectively process the large amount of image data acquired during UAV inspections, and through intelligent analysis, quickly identify potential problems and deterioration conditions of the equipment. For example, for insulator cracks, surge arrester damage, and conductor corrosion, the algorithm can provide accurate assessments of the degree of deterioration, offering timely decision support for maintenance personnel.

[0073] S103, Establish a comprehensive evaluation model and obtain the target equipment operating status based on the first deterioration amount, the second deterioration amount, and the third deterioration amount;

[0074] In this embodiment of the application, establishing a comprehensive evaluation model includes:

[0075] The comprehensive evaluation model is any model whose output is a comprehensive score of the target equipment's operating status and whose input is the deterioration analysis results.

[0076] The degradation analysis results include at least one or more of the first degradation amount, the second degradation amount, or the third degradation amount.

[0077] In an alternative embodiment, the comprehensive evaluation model can be trained on degraded data using machine learning algorithms such as support vector machines (SVM), random forests, gradient boosting decision trees, etc., to build a predictive model.

[0078] In an optional embodiment, the comprehensive evaluation model can also predict the future degradation trend of the equipment by utilizing historical and real-time data through time series analysis.

[0079] In an optional embodiment, the comprehensive evaluation model can also incorporate domain knowledge and empirical rules into the model by combining an expert system, thereby improving the accuracy and reliability of the evaluation.

[0080] In an optional embodiment, the comprehensive evaluation model can also use a multi-objective optimization algorithm to balance the impact of different degradation levels on the equipment operating status, so as to obtain a more comprehensive evaluation of the equipment status.

[0081] In an optional embodiment, the comprehensive evaluation model can also implement a dynamic update mechanism to continuously adjust and optimize model parameters based on newly collected data to adapt to changes in equipment status.

[0082] It should be noted that regardless of the method used to design the comprehensive evaluation model, as long as the output of the model is the comprehensive score of the target equipment's operating status and the input is the deterioration analysis result, it should be within the scope of protection of this application.

[0083] In this embodiment of the application, the comprehensive evaluation model includes:

[0084] The first, second, and third levels of degradation are scored using a first-level rating system.

[0085] The first-level scoring results are then used to conduct a second-level scoring to obtain a comprehensive score of the target equipment's operating status.

[0086] The comprehensive score for the operating status of the target equipment includes several scoring intervals, and each scoring interval corresponds to a unique status level.

[0087] In one optional embodiment, the first-level scoring can employ expert scoring, subjectively scoring the degradation amount based on the experience and knowledge of domain experts; it can also utilize a fuzzy logic scoring system to convert fuzzy degradation descriptions into specific score values; it can also employ the Analytic Hierarchy Process (AHP) to score the degradation amount hierarchically by constructing a hierarchical structure model; or it can implement a rule-based scoring system to score the degradation amount according to preset rules. All these related operations can achieve the first-level scoring.

[0088] It should be noted that the purpose of the first-level rating is to establish a corresponding rating system for the first, second, and third levels of degradation, so as to convert these quantities into comparable and operable rating values.

[0089] In this embodiment of the application, the first-level scoring includes:

[0090] Determine the percentage of samples in the state-aware data that have reached performance degradation conditions out of the total number of samples in the evaluation data.

[0091] Calculate the percentage of all state-sensing data samples that have reached the performance degradation condition out of all state-sensing data.

[0092] Determine the degree to which the state-aware data samples have degraded in performance;

[0093] The state-aware data are the first degradation amount, the second degradation amount, and the third degradation amount.

[0094] Specifically, let F1 be the percentage of samples reaching performance degradation conditions out of the total number of evaluated data samples; F2 be the percentage of all state-aware data samples reaching performance degradation conditions out of all state-aware data samples; and F3 be the degree to which the state-aware data samples have reached performance degradation. The formulas for calculating the three types of variables F1, F2, and F3 are as follows:

[0095]

[0096] Where I refers to the total number of data samples submitted for evaluation; i1 refers to the number of data samples submitted for evaluation that did not meet the performance degradation conditions.

[0097]

[0098] Where I refers to the total number of data samples participating in the evaluation; i2 refers to the number of times all samples did not reach the performance degradation condition during the period of sensing the operation status of the transmission line; K i This refers to the total state perception frequency of the i-th sample;

[0099] In this embodiment of the application, solving for variable F3 requires first calculating the degree to which the state-aware data deviates from the performance degradation condition limit (e ik When the indicator status perception data is below the performance degradation condition, it is considered that the performance degradation condition has not been met. ik This refers to positive indicators;

[0100]

[0101] Conversely, when state-aware data exceeds the performance degradation condition limit, it is considered that the performance degradation condition has not been met. ik This refers to a contrarian indicator;

[0102]

[0103] Among them, F3 ranges from 0 to 100, which can reflect the degree to which the variable reaches and exceeds the performance degradation condition.

[0104] In an optional embodiment, the second-level score, based on the first-level score, further considers the interactions and weights between different levels of degradation. It is calculated using a mathematical model or algorithm to obtain a more accurate and comprehensive equipment operating status score. For example, methods such as weighted average, principal component analysis (PCA), or factor analysis can be used to convert the first-level score into a final comprehensive equipment operating status score. This two-level scoring mechanism provides a more detailed reflection of the actual operating condition of the equipment, offering a more scientific basis for maintenance decisions.

[0105] In this embodiment of the application, the second-level score is solved using a weighted average method;

[0106] In an optional embodiment, the overall score of the target equipment's operating status can be based on a percentage system, a ten-point system, or a one-point system. However, regardless of the method used for scoring, the ultimate goal of the scoring is to provide an intuitive quantitative indicator so that operators and maintenance personnel can quickly understand the operating status of the equipment.

[0107] In this embodiment of the application, a percentage system is selected, and the equipment operation status level classification shown in Table 1 is designed;

[0108] Table 1 Classification of Equipment Operating Status Levels

[0109]

[0110] In an alternative embodiment, those skilled in the art can design more or fewer types of state levels, and can also change the score range according to the specific experiment; no limitation is made here.

[0111] It should be noted that the advantage of establishing a comprehensive evaluation model and obtaining the target equipment's operating status based on the first, second, and third degradation levels is that it enables real-time monitoring and prediction of equipment operating status, thereby identifying potential risks and faults in advance and reducing the probability of sudden failures. Furthermore, the comprehensive evaluation model provides a scientific basis for equipment maintenance, optimizes maintenance plans, improves maintenance efficiency, and reduces maintenance costs. In practical applications, this model helps power system operation and maintenance personnel better understand equipment status, achieve precise maintenance, and ensure the stable operation of transmission lines and the safety of power supply.

[0112] S104, complete the status perception based on the operating status of the target device.

[0113] In this embodiment of the application, the state perception based on the operating state of the target device includes:

[0114] Determine the status level based on the operating status of the target equipment;

[0115] Send an alarm notification for this status level to the equipment operation and maintenance department.

[0116] In an optional embodiment, the alarm notification form may include the following information: equipment name, equipment number, current status level, status level description, recommended maintenance measures, estimated maintenance time window, and emergency contact information. The alarm notification form is designed to provide maintenance personnel with clear and intuitive equipment status information for rapid response and appropriate maintenance measures. Furthermore, the alarm notification form should also include historical status records and trend analysis to help technicians assess the evolution of equipment status and make more reasonable maintenance decisions. In this way, the stable operation of high-voltage equipment in transmission lines can be ensured, potential faults can be prevented, and the continuity and reliability of power supply can be guaranteed.

[0117] In one optional embodiment, after sending an alarm notification for the status level to the equipment operation and maintenance department, the maintenance personnel will take corresponding maintenance measures based on the content of the alarm notification. These measures may include, but are not limited to, inspecting, repairing, or replacing parts of the equipment, and adjusting equipment operating parameters. By responding to alarm notifications in a timely manner, equipment failures can be effectively prevented, ensuring the stable operation of transmission lines.

[0118] In an optional embodiment, as shown in Figure 2, the method can be further refined to the content shown in Figure 2, Start: The process begins from the “Start” node.

[0119] Data Input: There are three different data sources input into the system: online monitoring data of transmission lines collected by non-contact sensors 201; drone inspection image recognition data of high-voltage equipment of transmission lines from the drone inspection and control platform 203; and manual inspection data of high-voltage equipment of transmission lines from the power grid management platform 205.

[0120] Data Analysis: Analyze each data source: Analyze the electrical and mechanical performance degradation conditions of online monitoring data 202; fuse and analyze the global line image and component local image from machine inspection image recognition data 204; analyze the electrical and mechanical performance degradation conditions of manual inspection data 206;

[0121] Solving the proportion and degree: Solving the percentage of samples that reach the performance degradation condition out of the total number of evaluation data samples F1207; Solving the percentage of all state-sensing data samples that reach the performance degradation condition out of all state-sensing data F2208; Solving the degree of performance degradation of the state-sensing data samples F3209.

[0122] Evaluation results: Based on the evaluation results of any one of the three types of state perception data, the operating state level 210 of the high-voltage equipment of the transmission line is solved;

[0123] Issue a notification: For operations in critical, abnormal, or alert status, issue a technical supervision alarm notification 211;

[0124] End: The process ends at the "End" node.

[0125] In summary, this invention proposes a panoramic perception method for the operating status of high-voltage equipment in transmission lines. The method acquires first monitoring data, first detection data, and first image data of the target equipment. Based on a preset degradation analysis method, degradation analysis is performed on the first monitoring data, first detection data, and first image data to obtain first degradation quantity, second degradation quantity, and third degradation quantity. A comprehensive evaluation model is established, and the operating status of the target equipment is obtained based on the first degradation quantity, second degradation quantity, and third degradation quantity. Status perception is completed based on the operating status of the target equipment. Through the establishment of the comprehensive evaluation model, a comprehensive assessment of the operating status of high-voltage equipment in transmission lines can be achieved, thereby providing more accurate and timely maintenance decision support. This method and system can effectively reduce the risk of power outages caused by equipment failures and improve the operational reliability of transmission lines. The use of non-contact monitoring technology reduces the requirements for equipment insulation performance, lowering maintenance costs and operational risks. Through multi-parameter fusion technology, real-time monitoring of equipment status is achieved, improving the comprehensiveness and accuracy of monitoring and evaluation.

[0126] This embodiment also provides a panoramic perception system for the operating status of high-voltage equipment in transmission lines, including:

[0127] The data acquisition module is used to acquire the first monitoring data, the first detection data, and the first image data of the target device;

[0128] The degradation processing module is used to perform degradation analysis on the first monitoring data, the first detection data, and the first image data according to a preset degradation analysis method to obtain the first degradation amount, the second degradation amount, and the third degradation amount.

[0129] The model building module is used to build a comprehensive evaluation model and obtain the operating status of the target equipment based on the first, second and third degradation levels.

[0130] The status awareness module is used to complete status awareness based on the operating status of the target device.

[0131] The above-mentioned unit modules can be embedded in the processor of the computer device in hardware form or independent of it, or they can be stored in the memory of the computer device in software form, so that the processor can call and execute the corresponding operations of the above modules.

[0132] This embodiment also provides a computer device, which can be a terminal, and its internal structure diagram is shown in Figure 6. The computer device includes a processor, memory, communication interface, display screen, and input device connected via a system bus. The processor provides computing and control capabilities. The memory includes a non-volatile storage medium and internal memory. The non-volatile storage medium stores an operating system and computer programs. The internal memory provides an environment for the operation of the operating system and computer programs in the non-volatile storage medium. The communication interface is used for wired or wireless communication with external terminals. Wireless communication can be achieved through Wi-Fi, carrier networks, NFC (Near Field Communication), or other technologies. When the computer program is executed by the processor, it implements a panoramic perception method for the operating status of high-voltage equipment in power transmission lines. The display screen can be a liquid crystal display (LCD) or an e-ink display. The input device can be a touch layer covering the display screen, buttons, a trackball, or a touchpad on the computer device's casing, or an external keyboard, touchpad, or mouse.

[0133] This embodiment also provides a computer-readable storage medium on which a computer program is stored, and when the computer program is executed by a processor, it performs the following steps:

[0134] Acquire the first monitoring data, first detection data, and first image data of the target device;

[0135] According to the preset degradation analysis method, the first monitoring data, the first detection data, and the first image data are subjected to degradation analysis to obtain the first degradation amount, the second degradation amount, and the third degradation amount;

[0136] A comprehensive evaluation model is established, and the operating status of the target equipment is obtained based on the first, second, and third degradation levels.

[0137] Status perception is achieved based on the operating status of the target equipment.

[0138] Example 2

[0139] According to another aspect of the present invention, a high-voltage equipment operation status perception system for transmission lines is also provided. This system carries a method and system for analyzing the operation status of high-voltage equipment, and constructs a status perception system applicable to overhead conductors, ground wires, surge arresters, insulators, and fittings of 110 kV and above overhead transmission lines. The software quality of the high-voltage equipment operation status panoramic perception system conforms to the specifications of GB / T 16260.1 "Software Engineering Product Quality Part 1: Quality Model", GB / T 16260.2 "Software Engineering Product Quality Part 2: Internal Quality", GB / T 16260.3 "Software Engineering Product Quality Part 3: External Quality", and GB / T 16260.4 "Software Engineering Product Quality Part 4: Measurement of Usage Quality". The high-voltage equipment operation status panoramic perception system comprises an infrastructure layer, a data layer, an application layer, and a presentation layer.

[0140] As an optional embodiment, the infrastructure layer deploys non-contact monitoring sensors for high-voltage equipment on transmission lines, including non-contact insulator leakage current monitoring sensors, non-contact overhead conductor broadband voltage monitoring sensors, and non-contact composite insulator temperature monitoring sensors. This avoids the potential hazards to transmission lines posed by contact sensor installation methods and features safety and anti-interference capabilities. The monitoring sensors process and collect equipment operating status information, store and process it on-site, and can interact with the main station system. Transmission management personnel regularly inspect, maintain, and statistically analyze the data to ensure stable operation of the monitoring sensors and accurate and reliable status perception data.

[0141] As an optional embodiment, the data layer is used to provide data support services and can provide a data foundation for the system presentation layer. This includes collecting online monitoring data on leakage current and temperature of transmission line insulators and voltage of overhead conductors collected from different monitoring sensors, collecting manual inspection data of high-voltage equipment of transmission lines from the power grid management platform (asset domain) of the power grid enterprise, and collecting visible light image recognition data of high-voltage equipment of transmission lines from the UAV inspection and control platform of transmission lines.

[0142] The data layer collects online monitoring data on the operating status of high-voltage equipment in transmission lines. The monitoring data station network should use IPv4 addresses, and the IP address settings within the network should meet the requirements of uniqueness, manageability, continuity, and scalability. The two planes of the station's dispatch data network should use independent IP address ranges, with plane A using the 10.0.0.0 / 8 private address range and plane B using the 20.0.0.0 / 8 address range. The panoramic perception system for the operating status of high-voltage equipment in transmission lines needs to use one of the following communication methods to transmit online monitoring data: a public communication network (excluding the Internet) or a wireless communication network (GPRS, CDMA, 230MHz, WLAN). A secure access zone should be established. The logical structure of the horizontal and vertical interconnections of the secure access zone, as well as the overall deployment of network security protection equipment, should be defined. Only equipment necessary for public network data collection (such as a public network front-end data collection server) and communication servers should be deployed within the secure access zone; functions unrelated to public network data collection should not be deployed within the secure access zone. The encryption and authentication measures of the online monitoring system for high-voltage equipment in transmission lines are deployed between the front-end data acquisition server and the public communication network. These measures are used for identity authentication and encryption and decryption of transmitted data in network data communication between the front-end data acquisition server and the monitoring sensors, ensuring the legitimacy of the system connection and the confidentiality, integrity, and non-repudiation of data transmission.

[0143] The horizontal network data network that collects manually monitored data on the operating status of high-voltage equipment in transmission lines should adopt a Quality of Service (QoS) mechanism based on the DiffServ service model to address network latency and congestion. It should employ QoS measures such as port rate limiting, traffic shaping, and queue scheduling to ensure network availability based on service requirements. When wide area network links are congested, priority bandwidth should be guaranteed for services with high real-time requirements. Differential Services Code Points (DSCPs) and EXP data fields should be used to identify service priorities.

[0144] The main equipment for horizontal and vertical interconnection between the UAV inspection and control platform for power transmission lines and the panoramic perception system for the operation status of high-voltage equipment on power transmission lines, and between the UAV inspection and control platform and the UAVs themselves, in the data layer includes interconnection switches for each status perception system, forward and reverse isolation devices, vertical encryption and authentication devices, firewalls, secure access zones, dispatch data networks, integrated data networks, and public communication networks. Redundant backup structures can be deployed for related communication equipment. Interconnection switches are used for the aggregation and access of business systems with horizontal and vertical data communication, access control between access systems, and horizontal and vertical interconnection of secure zones. Forward and reverse isolation devices are deployed at the network boundary between the non-control zone and the management information zone, providing physical isolation between the production control zone network and the management information zone network. This allows relevant business systems in the production control zone to send data to relevant business systems in the management information zone in a forward unidirectional manner; and relevant business systems in the management information zone to import plain text data to relevant business systems in the production control zone in a reverse unidirectional manner. The non-control zone vertical encryption authentication gateway is deployed between the non-control zone and the scheduling data network (non-real-time VPN). It is used for authentication, access control, and encryption / decryption of transmitted data during network data communication between relevant business systems or modules in the local non-control zone and the remote non-control zone, ensuring the legitimacy of system connections and the confidentiality and integrity of data transmission. When business systems in the production control zone need to use public communication networks, a secure access zone should be deployed, and the Internet should not be used for business data transmission.

[0145] As an optional implementation, the application layer performs data storage and computational processing, including assessing the electrical and mechanical performance degradation of high-voltage equipment in transmission lines, and evaluating and quantifying the operating status level of the high-voltage equipment. A neural network for analyzing the operating status of high-voltage equipment in transmission lines is deployed at the application layer (as shown in Figure 3). This neural network comprehensively analyzes online monitoring data, manual inspection data, and machine-generated image recognition data to confirm the performance degradation level of overhead conductors, ground wires, surge arresters, insulators, and hardware for 110 kV and above overhead transmission lines. Time-series curves of online monitoring data, manual inspection data, and machine-generated image recognition data are plotted, and the analysis results of different types of state perception data for the same equipment and the same insulation fault are fused and analyzed to avoid the impact of missing data for a certain type of state perception data on timely understanding of changes in equipment operating status. After deploying a neural network for analyzing the operational status of high-voltage equipment in transmission lines, and using this as a model, the application layer of the panoramic perception system for the operational status of high-voltage equipment in transmission lines covers potential electrical and mechanical performance hazards of overhead conductors, ground wires, surge arresters, insulators, and hardware in 110 kV and above overhead transmission lines. A shared area for storing and processing corresponding operational status perception data is established, integrating the source data and analysis results required by various data analysis algorithms for the same electrical or mechanical fault into a single data model object. This data sharing area provides an effective way for the concurrent operation and evaluation calculation of various data analysis algorithms. That is, fault information groups from the same fault period or different fault periods can be accessed and processed simultaneously from various analysis and processing subsystems. If the analysis of a certain insulation fault information by a new subsystem fails to meet the conditions, the system will switch to processing fault information from other equipment.

[0146] For manually inspected data used to assess the operating status of high-voltage equipment in transmission lines, the conditions for determining performance and mechanical degradation are as follows;

[0147] Optionally, the test results of the line arrester can be judged if the insulation resistance of the arrester body and supporting insulator is less than 1000 megohms, which can be judged as electrical performance degradation.

[0148] Optionally, the criteria for judging the results of the live insulator test are as follows: if the voltage value of the tested insulator is lower than 50% of the standard value, it can be judged as deterioration of electrical performance; if the voltage value of the tested insulator is higher than 50% of the standard value and is significantly lower than the voltage values ​​of the qualified insulators on both sides, it can be judged as deterioration of electrical performance.

[0149] Optionally, the criteria for judging the infrared temperature measurement results of the conductor and ground wire are that the following requirements are not met: the temperature of the conductor joint of the transmission line can be slightly higher than the conductor temperature, but should not exceed 10 degrees Celsius, and should not exceed the allowable operating temperature of the conductor. Considering the load changes at that time and in the previous hour as well as the atmospheric environmental conditions, it can be judged as electrical performance deterioration.

[0150] Optionally, the determination of the conductor sag measurement results is based on the following requirements: the allowable deviation range of the sag after stringing for 110 kV transmission lines is +5% to -2.5%, and the allowable deviation range of the sag after stringing for 220 kV and above transmission lines is ±2.5%; the allowable deviation value of the phase-to-phase sag of the conductors and overhead ground wires for 110 kV transmission lines is 200 mm, and the allowable deviation value of the phase-to-phase sag of the conductors and overhead ground wires for 220 kV and above transmission lines is 300 mm; the allowable deviation of the sag of the same-phase sub-conductors of the split conductors with spacers installed on the conductors of 220 kV transmission lines is 80 mm, and the allowable deviation of the sag of the same-phase sub-conductors of the split conductors with spacers installed on the conductors of 330 to 500 kV transmission lines is 80 mm, which can be judged as deterioration of electrical performance.

[0151] The following are the criteria for judging the performance and mechanical performance degradation of the electrical inspection image recognition data used to assess the operating status of high-voltage equipment in transmission lines;

[0152] Optionally, damage to the umbrella group or missing locking pins of the inspected insulators, tilting of the insulator string, cracks or breaks in the iron cap, corrosion or damage to the steel foot or discharge can be judged as mechanical performance deterioration;

[0153] Optionally, if the inspected overhead conductors and ground wires have loose strands, broken strands, broken wires, corrosion damage, or discharge, it can be determined that their mechanical properties have deteriorated.

[0154] Optionally, if the inspected line fittings have broken, detached, deformed, or corroded wire clamps, displaced, loosened, deformed, or corroded vibration dampers, displaced, loosened, or deformed spacers, damaged or cracked adjusting plates, or burned or loosened equalizing rings and shielding rings, it can be determined that the mechanical performance has deteriorated.

[0155] Optionally, if the surge arrester being inspected has loose leads, deformed discharge gaps, or burns, it can be determined that its electrical performance has deteriorated.

[0156] As an optional implementation, the presentation layer is used to display online monitoring data, manual inspection data, machine inspection image recognition data, time series curves, and operating status levels that reflect the electrical and mechanical performance of high-voltage equipment in transmission lines. The web server uses technologies such as Axis or Axis2 to implement interface services for corresponding businesses and deploys .aar interface services. A valid WebService interface address is obtained. The web server establishes an HTTPS service and publishes internal resources (web applications, HTTP protocol) on the service. The SSL VPN protocol provides basic authentication certificates and encryption / decryption algorithms. During data transmission, it first hands with the SSL VPN protocol server to reach an agreement on a protocol version, automatically selects the encryption algorithm and authentication method, and then encrypts the sent data according to the encryption algorithm. The SSL VPN protocol decrypts the data according to the encryption algorithm and forwards it to the policy router. When the power supply bureau's production command center and transmission management station's equipment maintenance personnel access the web server, they can use parameters or different ports (publishing multiple HTTPS services) to distinguish the resources to be redirected. It is compatible with GDCA digital certificates required by cryptographic algorithms such as SM2, SM3, SM4, and RSA to ensure certificate legitimacy.

[0157] This invention is not limited to the specific embodiments described above. The above are merely preferred embodiments of this invention and are not intended to limit the invention. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

[0158] Example 3

[0159] According to another aspect of the present invention, a more specific panoramic perception system for the operating status of high-voltage equipment in transmission lines is also provided. Figure 4 is a schematic diagram of the panoramic perception system for the operating status of high-voltage equipment according to an embodiment of the present invention. As shown in Figure 4, the system includes an infrastructure layer, a data layer, an application layer, and a presentation layer. The infrastructure layer deploys non-contact monitoring sensors for high-voltage equipment in transmission lines, including non-contact insulator leakage current monitoring sensors, non-contact overhead conductor broadband voltage monitoring sensors, and non-contact composite insulator temperature monitoring sensors. The data layer serves as a data foundation providing data support services and includes a front-end acquisition server, a horizontal acquisition server, a security access zone switch, and an intranet switch. The application layer includes an application server, a time-series database server, and a relational database server. The presentation layer includes a web server, an engineer's workstation, and an operator's workstation. The various layers of the system are connected to each other through a power integrated data network, and the monitoring sensors are connected to the security access zone switch through a public communication network.

[0160] The sensing layer deploys non-contact monitoring sensors for high-voltage equipment on transmission lines, mainly including leakage current monitoring sensors, wideband voltage monitoring sensors, and temperature monitoring sensors. These are installed near the overhead conductors and insulators of the transmission lines. The number of sensor measurement points is determined based on the scale of the high-voltage equipment to be monitored on the transmission line, and the online monitoring rate should be no less than 99%. The technical requirements of the monitoring sensors should comply with the provisions of GB / T 35697 "General Technical Specifications for Online Monitoring Devices for Overhead Transmission Lines". The field communication methods of the monitoring sensors should support at least one of the following three types: serial communication, short-range wireless communication, and network communication. The remote communication methods with the main station system should support at least wireless network communication, fiber optic communication, and satellite communication. The service life should be no less than 8 years, and the data loss rate should be less than 1%. The current measurement range of the insulator leakage current monitoring sensor is 50 to 50 mA, and the frequency measurement range is 10 Hz to 150 kHz. Wideband voltage... The monitoring sensor has a measurement bandwidth of 10 MHz, linearity of 2.3%, amplitude error of less than 1.3%, and phase error of less than 2.1°. The measurement range of the ordinary wire temperature sensor is -55 to +120 degrees Celsius, and the measurement accuracy is within ±1.0 degrees Celsius. The measurement range of the heat-resistant wire temperature sensor is -55 to +180 degrees Celsius, and the measurement accuracy is within ±1.0 degrees Celsius. The measurement range of the super / special heat-resistant wire temperature sensor is -55 to +290 degrees Celsius, and the measurement accuracy is within ±1.0 degrees Celsius.

[0161] The data layer mainly includes a front-end acquisition server, a horizontal acquisition server, a security access zone switch, and an intranet switch, all deployed in the communication room of the power supply bureau's production command center, with one set of each.

[0162] The data layer's front-end acquisition server and horizontal acquisition server are both NF5280M5 2U rack servers, configured with four 8-core Xeon E7-8893 V4 series CPUs, 14nm, supporting Hyper-Threading, with a cache of no less than 25 MB / s, a base clock speed of no less than 3.2 GHz, and a bus specification of QPI 9.6 GT / s; the memory configuration is no less than 128 Gigabytes of DDR4 memory, with a maximum total number of memory slots of no less than 64, and the slot type is LGA 2011; the hard drive configuration is four 600 Gigabyte, 12000 RPM serial-connected SCSI hard drives; the network card is equipped with no less than eight independent 10 / 100 / 1000M-BaseT Ethernet ports;

[0163] The data exchange, customized protocols, deployment architecture, data transmission security specifications, and protection mechanisms of the data layer front-end acquisition server should comply with the provisions of Q / CSG 1210017 "Technical Specifications for Internal and External Network Data Security Exchange Platform", Q / CSG 1210007 "Data Transmission Security Standards", and Q / CSG 1204009 "Technical Specifications for Security Protection of Power Monitoring Systems". It collects online monitoring data on insulator leakage current, overhead conductor broadband voltage, and composite insulator temperature through a secure access zone switch, providing data services to the time-series database server. The data layer front-end acquisition server scans the exchanged data and instructions through a firewall, closes abnormal ports, and prevents intrusion.

[0164] Optionally, data exchange refers to the transmission, reception, interpretation, and parsing of data.

[0165] The data exchange, customized protocols, deployment architecture, data transmission security specifications, and protection mechanisms of the horizontal acquisition server at the data layer should comply with the provisions of Q / CSG 1210017 "Technical Specifications for Internal and External Network Data Security Exchange Platform", Q / CSG 1210007 "Data Transmission Security Standards", and Q / CSG 1204009 "Technical Specifications for Security Protection of Power Monitoring Systems". It collects manual inspection data related to transmission line surge arrester testing, insulator live-line detection, conductor and ground wire infrared thermography, and conductor and ground wire sag measurement from the intermediate database server of the power grid management platform (asset domain) via the internal network switch. It also collects visible light image recognition data of overhead conductors, ground wires, surge arresters, insulators, and fittings from the intermediate database server of the transmission line UAV inspection and control platform, and provides data services to the relational database server.

[0166] The number of internal network switches is 1 set, which is deployed in the communication room of the power supply bureau's production command center. The physical interface, protocol, interconnection and compatibility requirements of the internal network switches shall comply with the provisions of Q / CSG 1204016.3 "Part 3: Technical Requirements for Data Network Equipment" and shall be used to connect the data layer horizontal acquisition server, relational database data server, application server, web server, engineer station and operator station through the power integrated data network composed of optical fiber.

[0167] One secure access zone switch is deployed in the communication room of the power supply bureau's production command center. It is equipped with 24 10 / 100 / 1000 Mbps adaptive Ethernet ports, a switching capacity of no less than 150 Mbps, a Layer 2 and Layer 3 packet forwarding capacity of no less than 95 Mbps, a concurrent flow count of no less than 400,000 packets, a data packet forwarding latency of less than 1 millisecond, and supports LDP MD5, VRRP MD5, and NTP MD5 encryption authentication. The secure access zone switch is used to connect to the front-end data acquisition server and the real-time database data server via a power integrated data network composed of optical fibers.

[0168] The application layer mainly includes application servers, time-series database servers, and relational database servers, all deployed in the information computer room of the power supply bureau's production command center, with one set of each.

[0169] The application server is an NP3020 M5 tower server, equipped with four 10-core Xeon Silver series CPUs, supporting Hyper-Threading, with a cache of no less than 20 megabytes and a base clock speed of no less than 3.4 GHz; the memory configuration is no less than 128 gigabytes of DDR4 memory, with a maximum total number of memory slots of no less than 64; the hard drive configuration is two 600 gigabyte, 12,000 RPM serial-connected SCSI hard drives.

[0170] Both the time-series database server and the relational database server are NF5280M5 2U rack-mount servers, equipped with two 8-core Xeon E7 V4 series CPUs supporting Hyper-Threading, with a cache of at least 25 megabytes and a native clock speed of at least 1.9 GHz; the memory configuration is at least 128 gigabytes of DDR4 memory, with a maximum total number of memory slots of at least 64; the hard drive configuration is four 600 gigabyte, 12,000 RPM serial-connected SCSI hard drives; the network card is equipped with eight independent 10 / 100 / 1000M-BaseT Ethernet ports;

[0171] The application server deploys a neural network for analyzing the operational status of high-voltage equipment in transmission lines. The input layer takes into account online monitoring data, manual inspection data, and machine-generated image recognition data that characterize the operation of the high-voltage equipment at specific times. Online monitoring data includes monitoring data for insulator leakage current, broadband voltage of overhead conductors, and temperature of composite insulators. Manual inspection data includes data from surge arrester tests, insulator live-line testing, infrared thermography of conductors and ground wires, and sag measurement of conductors and ground wires. Machine-generated image recognition data includes image recognition data for overhead conductors, ground wires, surge arresters, insulators, and hardware. The hidden layer analyzes the degree of degradation of the electrical and mechanical performance of the high-voltage equipment, calculates the initial value of the operating status level of the high-voltage equipment, and plots time-series curves of the online monitoring data, manual inspection data, and machine-generated image recognition data. The output layer displays the online monitoring data, manual inspection data, machine-generated image recognition data, time-series curves, and operating status level of the high-voltage equipment, and provides data services to the web server via an internal network switch.

[0172] The real-time database server and relational database server are used to store online monitoring data, manual inspection data, machine inspection image recognition data, and ledger information of high-voltage equipment in transmission lines, as well as relevant data on the performance degradation degree, status perception data time series, and operating status level of high-voltage equipment. Their data exchange, customized protocols, data transmission security specifications, and protection mechanisms should comply with the provisions of GB / T 20273 "Security Technical Requirements for Database Management Systems" and Q / CSG 1210007 "Data Transmission Security Standard". The relational database server is used to store manual inspection data, equipment ledger information, and operating status analysis-related data. The real-time database server is used to store online monitoring data and provides data services to the application server through the intranet switch.

[0173] The presentation layer mainly includes a web server, an engineer station, and an operator station. The web server is deployed in the communication room of the power supply bureau's production command center, while the engineer station and operator station are deployed in the central control room of the power supply bureau's production command center. There is one set of each.

[0174] The web server is an NF5280M5 2U rack server, equipped with two 8-core Xeon E7 V4 series CPUs supporting Hyper-Threading, with a cache of at least 25 megabytes and a native clock speed of at least 1.9 GHz; the memory configuration is at least 128 gigabytes of DDR4 memory, with a maximum total number of memory slots of at least 64; the hard drive configuration is four 600 gigabyte, 12,000 RPM serial-connected SCSI hard drives; the network card is equipped with eight independent 10 / 100 / 1000M-BaseT Ethernet ports;

[0175] The access technology measures for the web server should comply with the provisions of Q / CSG 1204009 "Technical Specifications for Security Protection of Power Monitoring Systems" and the management measures should comply with the provisions of Q / CSG 212001 "Management Measures for Security Protection of Power Monitoring Systems". The application system requirements should comply with the provisions of DL / T 1352 "Technical Guidelines for Power Emergency Command Centers". The access verification requirements for the power supply bureau's production command center and the equipment maintenance personnel of the transmission management office should comply with the provisions of GB / T 20272 "Technical Requirements for Operating System Security".

[0176] The engineering workstation is a dual-channel ThinkStation P310 series workstation.

[0177] The configuration principles and technical requirements of the engineering station should comply with the requirements of Q / CSG 1203005 "Technical Guidelines for Secondary Power Equipment" regarding computer monitoring systems, and be used to provide services for system administrators to maintain the panoramic perception system for the operation status of high-voltage equipment.

[0178] The operator station is a ThinkStation K series workstation.

[0179] The configuration principles and technical requirements of the operator station should comply with the requirements of Q / CSG 1203005 "Technical Guidelines for Secondary Power Equipment" regarding computer monitoring systems, and be used to provide system administrators and on-duty personnel with technical services related to monitoring and early warning, emergency response, load transfer, emergency power restoration, technical upgrades and repairs, and material allocation.

[0180] Example 4

[0181] In the specific installation and deployment of the panoramic perception system for the operation status of high-voltage equipment, firstly, key transmission lines of the year are selected, especially high-voltage equipment with historical or family-related defects. Secondly, according to the equipment scale requirements, non-contact monitoring sensors for the high-voltage equipment of the transmission lines, mainly including leakage current monitoring sensors, broadband voltage monitoring sensors, and temperature monitoring sensors, are installed near the equipment body of the overhead conductors and insulators of the transmission lines; at the same time, a monitoring sensor ledger is established, including classification by line voltage level, registering the corresponding line name, tower number, equipment type, and original equipment ID of the monitoring sensor. Thirdly, the front-end acquisition server, horizontal acquisition server, security access zone switch, and intranet switch of the data layer are deployed in the communication room of the power supply bureau's production command center; the application server, time-series database server, and relational database server of the application layer are deployed in the information room of the power supply bureau's production command center; the web server of the presentation layer is deployed in the communication room of the power supply bureau's production command center; and the engineer station and operator station of the presentation layer are deployed in the central control room of the power supply bureau's production command center (the number of each system equipment is 1 set), and digital certificates are applied for and network channels are confirmed. Finally, the power supply bureau's production command center should conduct routine monitoring and analysis of the operating status of high-voltage equipment daily, monitor and track defects and hidden dangers of high-voltage equipment on key transmission lines throughout the year, promptly issue technical supervision alarm notices to the transmission management office, and track them to the node closed loop.

[0182] Optionally, the operating status of a transmission line refers to the condition of the high-voltage equipment itself, the condition of the transmission line environment, and the impact of the surrounding environment during the operation of the transmission line.

[0183] Optionally, state quantities refer to physical quantities that reflect the state of the transmission line equipment, meteorological environment, and channel conditions.

[0184] Technical personnel at the power supply bureau's production command center discovered abnormal operational status sensing data from the panoramic perception system for high-voltage equipment operation on transmission lines. This was observed in conjunction with wiring diagrams, maps, and charts, and the charts and detailed data displays of the line monitoring data processing results were also examined. With the assistance of a neural network for analyzing the high-voltage equipment's operational status, an initial assessment was made that the high-voltage equipment voltage was abnormal. The entire process of this example demonstrates that, since the electric field component is directly proportional to the induced voltage, it is equivalent to a direct proportional relationship between the spatial electric field and the sensor's induced voltage. The non-contact broadband voltage monitoring sensor based on the vector electric field coupling principle utilizes the linear relationship between the electric field around a charged overhead conductor and the conductor's voltage. By increasing the inter-electrode capacitance, the measurement accuracy and response speed of the vector electric field sensor can be improved, enabling broadband measurement of transmission line voltage. A non-contact broadband voltage monitoring sensor is placed below the three-phase overhead conductors of a power transmission line (as shown in Figure 5). In the figure, the three overhead conductors A, B, and C are equivalent to a three-phase AC transmission line with voltages UA, UB, and UC, respectively. The sensor center is d away from the overhead conductors, the overhead conductors are H away from the ground, the phase spacing of the three overhead conductors is L, and the radius of the power transmission line is ρ. When the broadband voltage monitoring sensor is directly below phase B conductor, it is symmetrically distributed at the same distance from phases A and C. Assuming the equivalent spacing between the plates is l and ε0 is the dielectric constant, the electric field signal is integrated along the path of the plate spacing from the measuring point, and the proportionality coefficient between the induced voltage and the transmission line voltage is calculated. At this point, considering that the sensor is symmetrically distributed about the x, y, and z axes and placed directly below the middle phase of the transmission line, as well as the sensor's structural characteristics and signal output method, a decoupling matrix between the transmission line voltage and the spatial electric field is established in a three-dimensional coordinate system based on a single sensor. The relationship between the sensor output signal and the spatial electric field is solved, and the transmission line voltage is obtained based on the proportional relationship between the induced voltage and the electric field component.

[0185] The main implementation details in the specific handling process are as follows:

[0186] In one exemplary implementation, the power supply bureau's transmission management office, in conjunction with the power research institute and the power supply bureau's production technology department, conducts a comprehensive analysis based on cases of electrical or mechanical performance degradation detected by online monitoring and early warning systems. This analysis considers data such as weather conditions, geographical environment, line log information, and on-site fault inspection information in the fault section, combined with the characteristics of the line equipment and past fault experience. First, the fault type of the high-voltage equipment on the transmission line is determined, and targeted C-class, D-class, or E-class maintenance, such as infrared thermal imaging temperature measurement, is carried out. Furthermore, the cause of the fault should be diagnosed according to the fault type. For example, if the initial assessment is that the fault type of the high-voltage equipment on the transmission line is external force damage, the cause should be further determined to be a wildfire, tree obstruction, or nearby large-scale machinery construction. C-class maintenance refers to testing and work requiring line shutdown, including general defect elimination work requiring line shutdown; D-class maintenance refers to ground or ground potential inspection, testing, maintenance, and replacement work that does not require power shutdown; and E-class maintenance refers to inspection, testing, maintenance, and replacement work carried out using live-line working methods.

[0187] In one exemplary implementation, the power supply bureau's production command center, in conjunction with the power dispatching department, guides the power supply bureau's transmission management office to take emergency power outages and load transfer measures for equipment confirmed by live-line testing and diagnostic tests to have abnormal conductor / ground wire sag. Following the goal of restoring power, they conduct emergency fault handling such as adjusting conductor / ground wire sag and repairing faulty equipment to ensure the safe and stable operation of the power system. Specifically, the repair of faulty equipment must adhere to the relevant guidelines and process requirements of the high-voltage equipment manufacturer, developing specific repair plans and work instructions. The work instructions clearly define the requirements for the repair environment, organizational measures, technical measures, safety measures, procedures, and process quality standards. Repair work is strictly carried out in accordance with the work instructions. Faulty equipment repair work mainly includes Class A repairs and Class B repairs. Category A maintenance refers to technical upgrades that require power outages, mainly including large-scale maintenance work on line units that support energized operation, such as tower replacement and upgrades, conductor and ground wire replacement, batch replacement of insulators, and other technical upgrades involving power outages. Category B maintenance refers to maintenance work that requires power outages, mainly including maintenance work on line units that support energized operation or other work involving power outages to eliminate major or above defects and improve safety and reliability, such as tower component replacement, minor insulator replacement, and surge arrester replacement.

[0188] In one exemplary implementation, the power supply bureau's transmission management office, in conjunction with the supply chain department, procures or allocates replacement spare parts for specific high-voltage equipment exhibiting deterioration in electrical or mechanical performance. These spare parts include crossarms or main components, insulators, surge arresters, hardware, spacers, vibration dampers, anti-flashover coatings, and other maintenance and technical upgrade materials to support emergency power restoration. The spare parts should be provided by the original manufacturer and be of the same material and quality as the original equipment. Spare parts should be processed and packaged according to requirements, and individually boxed. The boxes should be clearly marked, and the spare parts should indicate their expiration date and necessary structural diagrams. Specialized tools and instruments should be accompanied by technical parameters, instruction manuals, and other relevant documentation.

[0189] In one exemplary implementation, after emergency response, technical upgrades and repairs, the equipment maintenance personnel of the power supply bureau's transmission management office assess the effectiveness of the panoramic perception of equipment operation status, determine whether the monitoring sampling points are sufficient and whether their locations are appropriate, and propose plans for adding or adjusting sensors.

[0190] Example 5

[0191] According to another aspect of the present invention, a computer solid-state readable storage medium is also provided, the computer solid-state readable storage medium including a program developed based on an integrated development environment (IntelliJ IDEA) stored thereon, wherein, when the program is running, it controls the device where the computer solid-state readable storage medium is located to execute the above-described method for analyzing the operating status of high-voltage equipment for transmission lines.

[0192] Optionally, in this embodiment, the computer solid-state readable storage medium may be located in any computer terminal in a group of computer terminals in a computer network, or in any mobile terminal in a group of mobile terminals, and the computer solid-state readable storage medium includes a stored program.

[0193] According to another aspect of the present invention, a digital integrated circuit is also provided, which is used to run a program, wherein the program executes the high-voltage equipment operating status analysis method described above when it runs.

[0194] This invention provides a device that includes a digital integrated circuit, a memory, and a program stored in the memory and executable on the digital integrated circuit. When the digital integrated circuit executes the program, it implements the steps of a high-voltage equipment operating status analysis method.

[0195] The sequence numbers of the above embodiments of the present invention are for descriptive purposes only and do not represent the superiority or inferiority of the embodiments.

[0196] In the above embodiments of the present invention, the descriptions of each embodiment have different focuses. For parts not described in detail in a certain embodiment, please refer to the relevant descriptions of other embodiments.

[0197] In the several embodiments provided in this application, it should be understood that the disclosed technical content can be implemented in other ways. The system embodiments described above are merely illustrative; for example, the division of units can be a logical functional division, and in actual implementation, there may be other division methods. For instance, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the shown or discussed mutual coupling, direct coupling, or communication connection may be through some interfaces, and the indirect coupling or communication connection of units or modules may be electrical or other forms. 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 units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0198] Furthermore, the functional units in the various embodiments of the present invention can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional module.

[0199] If the integrated unit is implemented as a software functional module and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present invention, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods described in the various embodiments of the present invention. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, read-only memory (ROM), random access memory (RAM), solid-state drives, magnetic disks, or optical disks.

[0200] The above description is only a preferred embodiment of the present invention. It should be noted that for those skilled in the art, several improvements and modifications can be made without departing from the principle of the present invention, and these improvements and modifications should also be considered within the scope of protection of the present invention.

Claims

1. A power transmission line high-voltage equipment operation state panoramic perception method, characterized in that, include: Acquire the first monitoring data, first detection data, and first image data of the target device; According to the preset degradation analysis method, the first monitoring data, the first detection data and the first image data are subjected to degradation analysis to obtain the first degradation amount, the second degradation amount and the third degradation amount; A comprehensive evaluation model is established, and the operating status of the target equipment is obtained based on the first, second, and third degradation amounts. Status perception is achieved based on the operating status of the target equipment.

2. The method for power transmission line high voltage equipment operating state panoramic perception according to claim 1, wherein, The establishment of the comprehensive evaluation model includes: The comprehensive evaluation model is any model whose output is a comprehensive score of the target equipment's operating status and whose input is the deterioration analysis result; The degradation analysis results include at least one or more of the first degradation amount, the second degradation amount, or the third degradation amount.

3. The method for power transmission line high voltage equipment operating state panoramic perception according to claim 2, characterized in that, The degradation analysis of the first monitoring data, the first detection data, and the first image data according to the preset degradation analysis method includes: The first image data is analyzed for degradation by using a preset first fusion recognition score algorithm to obtain the third degradation amount.

4. The panoramic perception method for the operating status of high-voltage equipment in transmission lines as described in claim 3, characterized in that, The comprehensive evaluation model includes: The first, second, and third degradation levels are scored using a first-level rating system. The first-level scoring results are then used to conduct a second-level scoring to obtain a comprehensive score of the target equipment's operating status.

5. The panoramic perception method for the operating status of high-voltage equipment in transmission lines as described in claim 4, characterized in that, The comprehensive score for the operating status of the target equipment includes several scoring intervals, and each scoring interval corresponds to a unique status level.

6. The panoramic perception method for the operating status of high-voltage equipment in transmission lines as described in claim 5, characterized in that, The first level of scoring includes: Determine the percentage of samples in the state-aware data that have reached performance degradation conditions out of the total number of samples in the evaluation data. Calculate the percentage of all state-sensing data samples that have reached the performance degradation condition out of all state-sensing data. Determine the degree to which the state-aware data samples have degraded in performance; The state-aware data includes a first degradation amount, a second degradation amount, and a third degradation amount.

7. The panoramic perception method for the operating status of high-voltage equipment in transmission lines as described in claim 6, characterized in that, The process of achieving state perception based on the target device's operating status includes: Determine the status level based on the operating status of the target equipment; Send an alarm notification for this status level to the equipment operation and maintenance department.

8. A panoramic perception system for the operating status of high-voltage equipment in transmission lines, characterized in that, include: The data acquisition module is used to acquire the first monitoring data, the first detection data, and the first image data of the target device; The degradation processing module is used to perform degradation analysis on the first monitoring data, the first detection data, and the first image data according to a preset degradation analysis method to obtain a first degradation amount, a second degradation amount, and a third degradation amount. The model building module is used to build a comprehensive evaluation model and obtain the target equipment operating status based on the first degradation amount, the second degradation amount, and the third degradation amount. The status awareness module is used to complete status awareness based on the operating status of the target device.

9. A computer device comprising a memory and a processor, wherein the memory stores a computer program, characterized in that, When the processor executes the computer program, it implements the steps of the method according to any one of claims 1 to 7.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by a processor, it implements the steps of the method according to any one of claims 1 to 7.

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