A fault detection method for an electric energy metering box

Abstract

This application relates to the field of power system fault detection technology, specifically to a fault detection method for an electricity metering box. It aims to address the problem in existing technologies where, during long-term cable use, potential faults such as joint oxidation, insulation damage, and stress concentration at bends are often randomly distributed throughout the cable link. Point-based monitoring cannot achieve continuous coverage, resulting in numerous long-term monitoring blind spots. This invention acquires temperature data across the entire cable link using a distributed fiber optic sensing system and identifies abnormal temperature rises in real time. Combined with multi-level threshold judgment and a precise location mechanism, it effectively solves the problem of delayed fault response caused by monitoring blind spots in existing technologies. It has the advantages of eliminating monitoring blind spots, timely detection of abnormal temperature rises, and precise fault location.

Description

Technical Field

[0001] This application relates to the field of power system fault detection technology, and more specifically, to a fault detection method for an electricity metering box. Background Technology

[0002] In the actual operation of electricity metering boxes, the potential for localized overheating of cables poses a significant threat to the safety of the power system. Existing temperature monitoring technologies mainly rely on point sensors, such as thermocouples or infrared temperature measuring devices. These devices can only be fixedly installed at specific locations on the cable, such as terminals or branch nodes.

[0003] During long-term use, cable faults such as joint oxidation, insulation damage, and stress concentration at bends are often randomly distributed throughout the entire cable link. Point-based monitoring cannot achieve continuous coverage, resulting in a large number of monitoring blind spots that persist for a long time. When abnormal temperature rises in blind spots, the system struggles to capture temperature change trends in real time. Detection usually occurs only when the temperature rises rapidly to near the ignition point or even ignites, by which time the fault has already progressed to an uncontrollable stage, severely delaying emergency response.

[0004] Furthermore, the lack of end-to-end temperature distribution data prevents maintenance personnel from accurately locating hotspots, increasing the risk of fire spread and potentially leading to misjudgments or response delays, significantly weakening the safety protection capabilities of electricity metering boxes. Existing technologies urgently need improvement to address these issues. Summary of the Invention

[0005] (a) Technical problems to be solved The purpose of this application is to provide a fault detection method and computer equipment for an electricity metering box, which has the advantages of enabling continuous temperature monitoring of the entire cable link in the electricity metering box, eliminating monitoring blind spots, timely detecting abnormal temperature rise and accurately locating the fault, thereby effectively preventing fire risks and improving the safety of the power system.

[0006] (II) Technical Solution This application provides a fault detection method for an electricity metering box, the technical solution of which is as follows: The methods include: Acquire temperature data of the entire cable link in the power metering box based on a distributed optical fiber sensing system; Based on temperature data, identify whether the cable is experiencing an abnormal temperature rise. When an abnormal temperature rise is detected, the corresponding fault warning or control command is output.

[0007] Furthermore, this application also proposes that obtaining temperature data of the entire cable link within the power metering box based on a distributed optical fiber sensing system includes: Acquire the scattered light signals transmitted back by distributed optical fiber sensors laid along the surface or inside of the cable; The scattered light signal is demodulated to obtain the real-time temperature value at least one measurement point per meter on the cable.

[0008] Furthermore, this application also proposes that, based on temperature data, identifying whether a cable exhibits an abnormal temperature rise includes: Calculate the temperature gradient between adjacent measurement points on the cable; Determine whether the temperature at any measurement point exceeds a first preset threshold, or whether the temperature gradient between adjacent measurement points exceeds a second preset threshold; If any of the judgment conditions are met, it is determined that there is an abnormal temperature rise.

[0009] Furthermore, this application also proposes that when an abnormal temperature rise is identified, the corresponding fault warning or control command should be output, including: If the temperature at any measurement point exceeds the first preset threshold but does not reach the third preset threshold, or if the temperature gradient exceeds the second preset threshold, an early warning signal containing abnormal location information will be output. If the temperature at any measurement point reaches or exceeds the third preset threshold, or if the temperature change rate is detected to exceed the fourth preset threshold, a control command to cut off the power supply to the power metering box will be output.

[0010] Furthermore, this application also proposes that the method further includes: Acquire ambient temperature and humidity data inside the electricity metering box; Temperature data is compensated and corrected based on ambient temperature and humidity data to eliminate interference from environmental factors affecting overall temperature rise.

[0011] Furthermore, this application also proposes that the optical fiber included in the distributed optical fiber sensing system is disposed within or beneath a ceramic-based composite nano-coating, the coating being applied to the outer surface of the cable insulation layer and / or the inner wall of the power metering box.

[0012] Furthermore, this application also proposes that the ceramic-based composite nanocoating is configured as follows: It has a thermal conductivity higher than the preset value, which is used to efficiently conduct the heat generated by the cable to the optical fiber; It has electromagnetic shielding effectiveness lower than a preset value to avoid interference with the signal acquisition of the metering chip inside the power metering box.

[0013] Furthermore, this application also proposes that, while outputting the control command to cut off the incoming power supply, the method further includes: Maintain backup power supply for the metering chip inside the power metering box to ensure that metering data is not lost after a power outage.

[0014] Furthermore, this application also proposes that the method further includes: Send fault warnings or control commands, along with corresponding temperature data and location information, to the remote operation and maintenance platform.

[0015] Furthermore, this application also proposes a computer device, including a processor and a memory, wherein the memory stores a computer program, and when the computer program is executed by the processor, the above-mentioned fault detection method for the electricity metering box is implemented.

[0016] (III) Beneficial Effects Compared with the prior art, the beneficial effects of the present invention are as follows: This invention acquires cable temperature data across the entire cable link through a distributed optical fiber sensing system and identifies abnormal temperature rises in real time. Combined with a multi-level threshold judgment and precise positioning mechanism, it effectively solves the problem of delayed fault response caused by monitoring blind spots in existing technologies. It has the advantages of eliminating monitoring blind spots, timely detecting abnormal temperature rises, and accurately locating faults. Attached Figure Description

[0017] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art 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.

[0018] Figure 1 This is a schematic diagram of the overall structure of a fault detection method for an electricity metering box. Detailed Implementation

[0019] The technical solutions of this application will now be clearly and completely described with reference to the accompanying drawings. Obviously, the described embodiments are merely some embodiments of this application, and not all embodiments. The components of this application described and shown in the accompanying drawings can generally be arranged and designed in various different configurations. Therefore, the following detailed description of the embodiments of this application provided in the accompanying drawings is not intended to limit the scope of the claimed application, but merely to illustrate selected embodiments of this application. All other embodiments obtained by those skilled in the art based on the embodiments of this application without inventive effort are within the scope of protection of this application.

[0020] It should be noted that similar reference numerals and letters in the following figures indicate similar items; therefore, once an item is defined in one figure, it does not need to be further defined and explained in subsequent figures. Furthermore, in the description of this application, terms such as "first," "second," etc., are used only to distinguish descriptions and should not be construed as indicating or implying relative importance.

[0021] Example 1

[0022] like Figure 1 As shown in the figure, this application proposes a fault detection method for an electricity metering box, including the following steps: S100. Acquire temperature data of the entire cable link in the power metering box based on the distributed optical fiber sensing system. S200: Based on temperature data, identify whether the cable has an abnormal temperature rise. S300: When an abnormal temperature rise is detected, output the corresponding fault warning or control command.

[0023] Specifically, a distributed optical fiber sensing system can be understood as a technology that can continuously sense changes in external physical quantities along an optical fiber path. It achieves distributed measurement of parameters such as temperature through the interaction between optical signals in the optical fiber and the external environment. For example, temperature information can be acquired through Raman scattering, Brillouin scattering, or Rayleigh scattering effects, primarily to achieve continuous monitoring of the temperature distribution throughout the entire cable link.

[0024] The process of acquiring temperature data can be achieved in various ways, such as segmented measurement using a fiber Bragg grating sensor array, or high-resolution scanning of temperature changes along the fiber using coherent optical time-domain reflectometry.

[0025] Specifically, the process of identifying whether a cable is experiencing an abnormal temperature rise can be implemented based on various algorithms. For example, a sliding window statistical analysis method can be used to process temperature data to determine whether there are any local temperature abrupt changes; or a machine learning model can be used to train historical temperature data to establish a benchmark for normal temperature rise patterns, and based on this, abnormal states that deviate from the normal pattern can be identified.

[0026] Furthermore, fault warnings or control commands can be output through various means. For example, warning signals can be presented as audible and visual alarms, or warning information can be sent to the maintenance terminal via a wireless communication module; for control commands, power cut-off operations can be implemented through relay control circuits, or tiered power-off strategies can be executed through intelligent switching devices.

[0027] The innovation of this application lies in its use of distributed fiber optic sensing technology to continuously collect temperature data of the entire cable chain within the power metering box, fundamentally solving the monitoring blind spot problem inherent in traditional point-based monitoring technologies. Simultaneously, through comprehensive analysis of the entire temperature data chain, abnormal temperature rise states of the cables can be quickly identified, and corresponding early warnings or control commands can be output based on the identification results, thus forming a closed-loop fault detection process. This method not only enables early detection and precise location of potential localized overheating hazards in cables but also maintains the continuity of power metering while ensuring electrical safety, effectively avoiding the adverse effects of fire spread or metering interruptions.

[0028] The working principle of this application embodiment is as follows: the temperature data of the entire cable link in the power metering box is collected through a distributed optical fiber sensing system. The distributed optical fiber sensing technology has continuous monitoring characteristics and can provide real-time temperature distribution information along the entire cable path, thereby eliminating the monitoring blind spots of traditional point sensors.

[0029] Furthermore, based on the acquired end-to-end temperature data, the system identifies whether the cable exhibits abnormal temperature rise through comprehensive data analysis. Specifically, this identification process relies on the continuity of the end-to-end temperature data, enabling rapid determination of whether abnormal temperature rises occur in localized areas, thus avoiding delays caused by limited monitoring range. Once an abnormal temperature rise is identified, corresponding fault warnings or control commands are output based on the identification results, thereby forming a tiered processing mechanism from warning to emergency control.

[0030] As a preferred implementation, the above three steps work closely together. The acquisition of end-to-end temperature data provides complete input for the identification of abnormal temperature rise, while the output of warning or control commands is based on the identification results. Together, they construct a closed-loop detection process to ensure that local overheating problems of cables can be accurately detected and dealt with in a timely manner at an early stage, effectively preventing the spread of fire or metering interruption.

[0031] This application further proposes to acquire the scattered light signal transmitted by a distributed optical fiber sensor laid along the surface or inside of the cable; and to demodulate the scattered light signal to obtain the real-time temperature value of at least one measurement point per meter on the cable.

[0032] In practical applications, distributed fiber optic sensors refer to devices that use optical fibers as the sensing medium and can achieve temperature sensing using the Raman scattering effect. Specifically, the Raman scattering effect refers to the interaction between a laser pulse propagating in an optical fiber and the temperature field at different locations along the fiber, resulting in a differential shift in the frequency of the scattered light signal. By analyzing the intensity and time difference of this frequency shift, the cable temperature value at each location in the fiber can be calculated. Furthermore, demodulation processing refers to the process of spectral analysis and data processing of the scattered light signal, aiming to extract the temperature information from the optical signal and convert it into a readable temperature value.

[0033] Specifically, this technical solution achieves continuous temperature monitoring across the entire cable chain by deploying distributed fiber optic sensors along the surface or interior of the cables within the power metering box. Compared to traditional point-based monitoring methods, distributed fiber optic sensors eliminate the need for independent sensors at each monitoring point. Instead, the entire cable chain is seamlessly covered by the fiber optic cables laid along the cable path. This design fundamentally solves the blind spot problem that traditional fixed-point monitoring cannot reach. Potential hazards such as cable joint oxidation, insulation damage, and stress concentration at bends can all be effectively detected. Simultaneously, setting a spatial resolution of at least one measurement point per meter ensures the precision of temperature data, preventing the omission of small-scale abnormal temperature rises due to sparse monitoring points. For example, a 10-centimeter length of insulation damage might be completely missed by traditional 5-10 meter resolution monitoring, while this solution, through its high spatial resolution design, can accurately identify such hazards.

[0034] Based on this, by demodulating the scattered light signal, not only can the real-time temperature values ​​of each measurement point on the cable be obtained, but the temperature change trend can also be recorded, providing a reliable data foundation for subsequent abnormal temperature rise identification. For example, when the temperature of a certain section of cable rises slowly at a rate of 0.5℃ / hour, the system can predict that it will reach the warning threshold in 3 hours through continuous temperature data, thereby achieving predictive maintenance. In addition, the high spatial resolution design can also accurately locate the fault location. For example, if the demodulation data shows an abnormal temperature at 2.3 meters of the cable, maintenance personnel can directly locate that location for repair without having to check each section, greatly improving maintenance efficiency. This technology based on distributed fiber optic sensing not only breaks through the limitations of traditional point monitoring, but also provides technical support for avoiding electromagnetic interference and ensuring measurement accuracy, forming a significant technical advantage.

[0035] This application further proposes a method for identifying whether a cable has an abnormal temperature rise based on temperature data, including: calculating the temperature gradient between adjacent measurement points on the cable; determining whether the temperature of any measurement point exceeds a first preset threshold, or whether the temperature gradient between adjacent measurement points exceeds a second preset threshold; if either judgment condition is met, it is determined that an abnormal temperature rise exists.

[0036] Specifically, the temperature gradient refers to the degree of temperature difference between adjacent measurement points on the cable, which can be calculated by subtracting the temperature data from continuous temperature data collected by a distributed fiber optic sensing system. The first preset threshold can be an absolute upper limit of temperature set based on the heat resistance performance of the cable material, such as 70℃ or 80℃, used to detect high-temperature risk points. The second preset threshold is a limit value for the drastic temperature change between adjacent measurement points, such as 10℃ / m, used to detect localized abnormal temperature rises. The purpose of introducing these technical features is to effectively distinguish between overall ambient temperature rise and potential localized overheating through dual criteria, thereby improving the comprehensiveness and reliability of fault detection.

[0037] In detail, this solution relies on continuous temperature data across the entire cable chain. By calculating the temperature gradient between adjacent measurement points, it can accurately identify temperature abrupt changes within a small range. For example, when the overall cable temperature is 40°C, if the temperature at a certain joint rises to 55°C due to oxidation, and the temperature difference between adjacent measurement points reaches 15°C, even if it does not exceed the first preset threshold, the anomaly can be identified by the gradient exceeding the second preset threshold.

[0038] Retaining the first preset threshold ensures direct monitoring of high-temperature risk points, avoiding missed detection of urgent hidden dangers. This design not only solves the problem that traditional single-threshold methods cannot distinguish between overall temperature rise and local overheating, but also cleverly balances the advantages of the two criteria through "OR logic": the gradient criterion focuses on capturing early minor hidden dangers, while the absolute temperature threshold deals with rapidly escalating high-temperature risks, forming a complementary coverage relationship between the two.

[0039] Since gradient calculation relies on the relative differences between adjacent measurement points, it is less affected by ambient temperature fluctuations, thus exhibiting higher stability in scenarios such as outdoor metering boxes. This technical solution enables accurate identification of localized abnormal temperature rises in cables, providing a reliable basis for subsequent graded response.

[0040] This application further proposes that when an abnormal temperature rise is detected, the corresponding fault warning or control command is output, including: if the temperature of any measurement point exceeds the first preset threshold but does not reach the third preset threshold, or the temperature gradient exceeds the second preset threshold, then a warning signal containing abnormal location information is output; if the temperature of any measurement point reaches or exceeds the third preset threshold, or the temperature change rate is detected to exceed the fourth preset threshold, then a control command to cut off the incoming power supply of the power metering box is output.

[0041] Specifically, the first preset threshold is the temperature limit used to determine if the cable is in the early stage of local overheating. It can be a fixed value set according to the heat resistance performance of the cable material, such as 60°C, with the aim of capturing the initial temperature rise of potential hazard points. The third preset threshold is the temperature limit used to determine if the cable has an immediate fire risk. It can be a higher value set according to the cable's ignition point, such as 150°C, with the aim of clarifying the triggering conditions for emergency response.

[0042] The second preset threshold refers to the maximum allowable temperature difference between adjacent measurement points. It can be a dynamic value set based on the temperature rise characteristics of the cable during normal operation, such as a temperature difference of no more than 5°C per meter. The purpose is to identify local anomalies such as joint oxidation or insulation damage. The fourth preset threshold refers to the rate limit of temperature change per unit time. It can be a value set based on cable short circuits or rapid heating scenarios, such as a temperature rise of more than 10°C per second. The purpose is to capture the dynamic characteristics of rapid fire development.

[0043] In detail, this solution achieves precise tiered processing of abnormal temperature rise states by constructing a multi-level response mechanism. First, when the temperature at any measurement point exceeds the first preset threshold but does not reach the third preset threshold, the system determines it as an early minor anomaly. It then makes a comprehensive judgment based on whether the temperature gradient exceeds the second preset threshold, thereby outputting an early warning signal containing information about the location of the anomaly.

[0044] This design not only effectively locates potential hazards but also prevents accidental power outages caused by slight temperature fluctuations, ensuring power supply continuity.

[0045] When the temperature at any measurement point reaches or exceeds the third preset threshold, or when the rate of temperature change is detected to exceed the fourth preset threshold, the system determines it as an emergency and severe anomaly and immediately outputs a control command to cut off the incoming power supply. This dual judgment logic, combining static thresholds and dynamic rate of change, can more accurately capture emergency risks in scenarios of rapid temperature rise, ensuring that the fastest and most effective protective measures are taken before a fire breaks out.

[0046] In addition, because the warning signal contains abnormal location information, maintenance personnel can directly locate the specific area, which greatly shortens the investigation time and improves the overall maintenance efficiency.

[0047] The above technical solutions not only resolve the contradiction between minor abnormalities causing accidental disconnection and severe abnormalities causing delayed response, but also provide efficient handling support for operation and maintenance, significantly improving the safety and reliability of the power metering box operation.

[0048] This application further proposes to obtain the ambient temperature and humidity data inside the power metering box; and to compensate and correct the temperature data based on the ambient temperature and humidity data in order to eliminate the interference of overall temperature rise caused by environmental factors.

[0049] Specifically, ambient temperature and humidity data refers to parameter information collected by sensors that reflects the current environmental state inside the power metering box. This can be achieved using integrated temperature and humidity sensors or discrete temperature and humidity sensors. In practical applications, compensation and correction refers to the process of dynamically adjusting the original temperature data based on the ambient temperature and humidity data. This can be achieved by establishing a correlation model between ambient temperature and humidity and the normal temperature rise of the cable, for example, by using experimental data to fit the specific influence of ambient temperature and humidity on cable temperature.

[0050] In detail, the solution first acquires real-time ambient temperature and humidity data through sensors deployed inside the power metering box, providing a basis for subsequent data processing. Based on this, and using a pre-built "environment-cable" two-dimensional correlation model, the collected ambient temperature and humidity data is comprehensively analyzed along with cable temperature data collected by the distributed fiber optic sensing system, thereby achieving dynamic correction of the original temperature data.

[0051] This correction method can effectively distinguish between the overall reference temperature rise caused by environmental changes and the local additional temperature rise caused by faults, thus eliminating the impact of environmental interference at the data source.

[0052] Furthermore, this solution works seamlessly with the aforementioned anomaly detection logic: by correcting the raw temperature data before inputting it into the temperature gradient criterion for further analysis, the accuracy of anomaly detection is significantly improved. For example, when a sudden rise in ambient temperature causes fluctuations in the overall temperature gradient of the cable, the corrected data can accurately determine whether the fluctuation is due to environmental interference, thereby preventing false alarms or accidental disconnections. Simultaneously, this solution possesses strong adaptability, allowing model parameters to be adjusted according to the climatic characteristics of different regions, making the technical solution applicable to complex environmental conditions nationwide.

[0053] This application further proposes that the optical fiber included in the distributed optical fiber sensing system is disposed within or beneath a ceramic-based composite nano-coating, the coating being applied to the outer surface of the cable insulation layer and / or the inner wall of the power metering box.

[0054] Specifically, ceramic-based composite nanocoatings refer to a multifunctional material with inorganic ceramics as the base and doped with nanoparticles. It can use high thermal conductivity ceramics such as alumina and silicon carbide as the base and achieve low electromagnetic shielding effectiveness by doping with semiconductor particles such as nano-tin oxide.

[0055] The purpose of this coating is to solve the problems of poor thermal conductivity and easy electromagnetic interference caused by traditional flame-retardant materials, while meeting the requirements of fire prevention and flame retardancy. The optical fiber is placed within or beneath the coating, meaning it is embedded inside the coating or fixed close to the lower surface of the coating. The purpose is to ensure that the optical fiber can quickly and accurately capture the heat changes generated by the cable by utilizing the coating's high thermal conductivity and anti-interference properties.

[0056] In detail, this solution creates a multifunctional integrated design by embedding optical fibers into a ceramic-based composite nano-coating. When the coating is applied to the outer surface of the cable's insulation, it directly captures the heat generated by the cable and efficiently conducts it to the optical fiber, significantly shortening the temperature measurement response time. When the coating is applied to the inner wall of the power metering box, it expands the temperature monitoring range and prevents cascading failures caused by overall temperature rise in the box. This design not only avoids the negative impact of traditional flame-retardant materials on temperature monitoring but also suppresses the influence of external electromagnetic interference on the optical fiber sensing signal through the coating's own physical isolation. Furthermore, the coating's high flame-retardant properties effectively protect the optical fiber and cable in the event of a fire, maintaining subsequent temperature monitoring capabilities and giving maintenance personnel more time to respond.

[0057] In summary, this technical solution achieves multiple functions such as high-efficiency heat conduction, low electromagnetic interference, and high fire resistance by combining optical fiber with ceramic-based composite nano-coating. It solves the key problems in temperature monitoring of the entire cable link while ensuring the non-destructive maintenance of measurement accuracy.

[0058] This application further proposes that the ceramic-based composite nanocoating is configured to: have a thermal conductivity higher than a preset value, for efficiently conducting the heat generated by the cable to the optical fiber; and have an electromagnetic shielding effectiveness lower than a preset value, for avoiding interference with the signal acquisition of the metering chip in the power metering box.

[0059] Specifically, ceramic-based composite nanocoatings refer to functional materials that achieve specific physical properties by controlling their composition and microstructure. They can be achieved using alumina ceramic as a substrate and doped with 5-8% nano-tin oxide particles, aiming to maintain low electromagnetic shielding characteristics while ensuring high thermal conductivity.

[0060] The thermal conductivity being higher than the preset value refers to the threshold set according to the short-distance temperature measurement requirements of the cables in the power metering box, which is usually ≥15W / (m·K) to ensure that heat can be conducted from the cable to the optical fiber within 2 seconds.

[0061] In detail, this solution addresses the dual challenges of low heat conduction efficiency and electromagnetic signal interference through a special design of a ceramic-based composite nano-coating. The coating's high thermal conductivity allows heat generated during cable operation to be quickly and evenly transferred to the fiber optic sensor, avoiding the heat accumulation problem caused by the poor thermal conductivity of traditional flame-retardant materials, thus enabling earlier detection of localized overheating in the cable.

[0062] Meanwhile, the coating's low electromagnetic shielding properties effectively suppress electromagnetic interference to the signal acquisition path of the metering chip, eliminating the risk of signal distortion that the material itself might introduce, and maintaining the original integrity of the current and voltage signals. This design not only optimizes the sensitivity of the fiber optic sensor but also ensures the stability of the metering function, allowing the coating to be fire-retardant without sacrificing core performance. Furthermore, the coating, combined with the overall design of the distributed fiber optic sensing system and the power metering box, forms a complete solution that improves the response speed of temperature monitoring while ensuring the accuracy of metering data.

[0063] The above technical solution enables accurate monitoring of the temperature of the entire cable chain within the power metering box, while avoiding interference with the signal acquisition of the metering chip, thus meeting the reliability requirements of the power metering system.

[0064] This application further proposes that while outputting a control command to cut off the incoming power supply, a backup power supply should be maintained for the metering chip inside the power metering box to ensure that the metering data is not lost after a power outage.

[0065] Specifically, a backup power supply refers to a power supply module independent of the main power supply, which can be implemented using low-power lithium thionyl chloride batteries, supercapacitors, or other energy storage devices with float charging capabilities. In practical applications, the backup power supply design must be adapted to the power consumption characteristics of the metering chip to ensure continuous power supply for at least 72 hours in emergency power outage scenarios. Maintaining power supply to the metering chip refers to seamlessly switching to the backup power supply the instant the main power supply is cut off, thereby ensuring the continuous operation of the core functional modules of the metering chip through hardware circuit design. The purpose of introducing this technical feature is to resolve the contradiction between emergency power outages and metering continuity, avoiding the problem of metering data loss or write interruption due to power outages.

[0066] In detail, when the system detects that the temperature reaches or exceeds the third preset threshold, the MCU will output a command to cut off the incoming power supply and simultaneously trigger the backup power supply switching mechanism. This process is achieved through a zero-delay switching circuit, specifically, under the control of the MOSFET switch, the backup power supply can take over the power supply of the core functional modules of the metering chip within 100 microseconds, including the data storage unit and the communication unit.

[0067] This rapid switching mechanism ensures that the metering chip will not fail due to power outages when performing critical operations, such as writing data to EEPROM or uploading real-time power consumption data. Furthermore, the backup power supply only powers the core functional modules of the metering chip, not the entire metering system. This not only reduces power consumption but also avoids the potential risks caused by overloading the backup power supply. Combined with the fault detection function of the distributed fiber optic sensing system, this solution achieves both fire safety goals and ensures the integrity of metering data, reflecting a balance between the dual requirements of "safety and emergency response" and "metering reliability" in the power system.

[0068] The above technical solution not only solves the problem of data loss due to power outages but also provides complete data support for remote operation and maintenance platforms. For example, in the event of an emergency power outage, the metering chip can upload key data from before the power outage to the platform via the communication module, thereby meeting the needs of accident tracing and billing settlement. Furthermore, this solution complies with the relevant requirements of JJG 596-2012 Electronic AC Energy Meters, improving the compliance and reliability of the metering system.

[0069] This application further proposes sending fault warnings or control commands, along with corresponding temperature data and location information, to a remote operation and maintenance platform.

[0070] Specifically, a remote operation and maintenance platform refers to a cloud-based or centralized management system that can receive and process fault-related information from a local system. It can be implemented using a server architecture based on Internet of Things (IoT) protocols.

[0071] In practical applications, the platform typically includes a data storage module, an analysis module, and a visualization interface, with the aim of providing real-time monitoring and decision support for operations and maintenance personnel.

[0072] Temperature data refers to the real-time temperature values ​​at various measurement points along the entire cable link, collected by a distributed fiber optic sensing system. This data can be stored and managed using a time-series database for subsequent analysis of abnormal temperature rise trends. Location information refers to the physical coordinates or identifiers of the specific cable segment where the abnormal temperature rise occurred. This information can be precisely located by combining the spatial resolution characteristics of the distributed fiber optic sensors.

[0073] In detail, this technical solution achieves seamless integration between local detection and maintenance response by establishing a remote transmission channel for fault information. First, after the distributed fiber optic sensing system collects temperature data across the entire cable link, the system determines whether there is an abnormal temperature rise based on preset thresholds. If an anomaly is detected, a corresponding fault warning or control command is generated, and this information, along with the temperature data and location information, is packaged and sent to the remote maintenance platform.

[0074] This process ensures that abnormal signals can overcome physical location limitations and be transmitted to the operations and maintenance center in real time, thus avoiding response delays caused by on-site personnel failing to detect or handle the issues promptly. Simultaneously, the information received by the remote operations and maintenance platform includes not only warnings or control commands but also detailed temperature data and location information, enabling the operations and maintenance team to quickly diagnose the root cause of problems without relying on on-site investigation. For example, temperature data can be used to analyze the specific degree and evolution trend of abnormal temperature rises, while location information helps to accurately pinpoint the cable segment where the fault occurred. This design significantly shortens fault analysis and decision-making time, allowing potential risks to be effectively controlled in their early stages.

[0075] Furthermore, combining the above-mentioned solution with the efficient data acquisition capabilities of the distributed fiber optic sensing system further enhances the overall performance of the system. By deeply integrating local sensing results with the remote operation and maintenance system, a closed-loop management system from data acquisition to remote handling is formed, which not only strengthens the system's real-time monitoring capabilities but also ensures the continuity and security of metering services.

[0076] Example 2

[0077] In another embodiment, this application also discloses a computer device, including a processor and a memory, wherein the memory stores a computer program, and when the computer program is executed by the processor, the above-mentioned fault detection method for the electricity metering box is implemented.

[0078] This computer equipment integrates hardware and software resources to provide a dedicated execution platform for fault detection of power metering boxes, thereby solving the problem that it is impossible to simultaneously achieve accurate early warning of local overheating of the entire cable link, high reliability fire prevention and flame retardancy, and lossless metering accuracy.

[0079] Specifically, the computer equipment, as the overall carrier, ensures the stable implementation of the fault detection method; the processor and memory constitute the core processing unit, supporting real-time data processing and storage; the computer program stored in the memory encodes the fault detection logic, enabling the equipment to automatically identify anomalies; when the program is executed by the processor, it directly implements the fault detection method, outputting warnings or control commands to avoid potential hazards caused by localized overheating. The synergistic effect of these features—the computer equipment providing the operational foundation, the processor and memory efficiently processing data and ensuring program execution, and the computer program transforming the fault detection method into operable instructions—forms a closed-loop system. This system achieves accurate end-to-end monitoring to prevent overheating, avoids misjudgments through reliable execution, maintains measurement accuracy, and ultimately achieves the unity of these three objectives.

[0080] The core innovation of this embodiment lies in combining distributed fiber optic sensing technology with computer equipment. By utilizing processors and memory to perform real-time analysis and processing of temperature data across the entire cable supply chain, it achieves early detection and precise location of potential localized overheating hazards. This ensures both electrical safety and continuous power metering. Furthermore, through comprehensive analysis of the temperature data across the entire supply chain, abnormal temperature rises can be quickly identified, and corresponding warnings or control commands can be output based on the identification results, effectively preventing the spread of fire or metering interruptions.

[0081] This application proposes a fault detection method for an energy metering box, including: acquiring temperature data of the entire cable link in the energy metering box based on a distributed optical fiber sensing system; identifying whether there is an abnormal temperature rise in the cable based on the temperature data; and outputting a corresponding fault warning or control command when an abnormal temperature rise is identified.

[0082] In practical applications, a distributed fiber optic sensing system can be understood as a technology capable of continuously sensing changes in external physical quantities along a fiber optic path. It achieves distributed measurement of parameters such as temperature through the interaction between optical signals in the fiber and the external environment. For example, temperature information can be acquired through Raman scattering, Brillouin scattering, or Rayleigh scattering effects, primarily to achieve continuous monitoring of the temperature distribution throughout the entire cable link. Furthermore, the process of acquiring temperature data can be implemented in various ways, such as segmented measurement using fiber Bragg grating sensor arrays, or high-resolution scanning of temperature changes along the fiber optic line using coherent optical time-domain reflectometry (CODR).

[0083] Specifically, the process of identifying whether a cable is experiencing an abnormal temperature rise can be implemented based on various algorithms. For example, a sliding window statistical analysis method can be used to process temperature data to determine whether there are any local temperature abrupt changes; or a machine learning model can be used to train historical temperature data to establish a benchmark for normal temperature rise patterns, and based on this, abnormal states that deviate from the normal pattern can be identified.

[0084] Furthermore, fault warnings or control commands can be output through various means. For example, warning signals can be presented as audible and visual alarms, or warning information can be sent to the maintenance terminal via a wireless communication module; for control commands, power cut-off operations can be implemented through relay control circuits, or tiered power-off strategies can be executed through intelligent switching devices.

[0085] The innovation of this application lies in its use of distributed fiber optic sensing technology to continuously collect temperature data of the entire cable chain within the power metering box, fundamentally solving the monitoring blind spot problem inherent in traditional point-based monitoring technologies. Simultaneously, through comprehensive analysis of the entire temperature data chain, abnormal temperature rise states of the cables can be quickly identified, and corresponding early warnings or control commands can be output based on the identification results, thus forming a closed-loop fault detection process. This method not only enables early detection and precise location of potential localized overheating hazards in cables but also maintains the continuity of power metering while ensuring electrical safety, effectively avoiding the adverse effects of fire spread or metering interruptions.

[0086] Temperature data of the entire cable link in the power metering box is collected by a distributed optical fiber sensing system. The distributed optical fiber sensing technology has continuous monitoring characteristics and can provide real-time temperature distribution information along the entire cable path, thereby eliminating the monitoring blind spots of traditional point sensors.

[0087] Based on the acquired end-to-end temperature data, the system identifies whether the cable exhibits abnormal temperature rise. Specifically, this identification process relies on the continuity of the end-to-end temperature data to quickly determine whether abnormal temperature rises occur in localized areas, avoiding delays caused by limited monitoring range. Once an abnormal temperature rise is identified, corresponding fault warnings or control commands are output based on the identification results, thus forming a tiered processing mechanism from warning to emergency control.

[0088] As a preferred implementation, the above three steps work closely together. The acquisition of end-to-end temperature data provides complete input for the identification of abnormal temperature rise, while the output of warning or control commands is based on the identification results. Together, they construct a closed-loop detection process to ensure that local overheating problems of cables can be accurately detected and dealt with in a timely manner at an early stage, effectively preventing the spread of fire or metering interruption.

[0089] The above description is merely an embodiment of this application and is not intended to limit the scope of protection of this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the scope of protection of this application.

Claims

1. A fault detection method for an electricity metering box, characterized in that, The method includes: Acquire temperature data of the entire cable link in the power metering box based on a distributed optical fiber sensing system; Based on the temperature data, it can be determined whether the cable is experiencing an abnormal temperature rise. When an abnormal temperature rise is detected, the corresponding fault warning or control command is output.

2. The fault detection method for an electricity metering box according to claim 1, characterized in that, The acquisition of temperature data for the entire cable link within the power metering box, collected by a distributed optical fiber sensing system, includes: Acquire the scattered light signal transmitted back by a distributed optical fiber sensor laid along the surface or inside of the cable; The scattered light signal is demodulated to obtain the real-time temperature value at least one measurement point per meter on the cable.

3. The fault detection method for an electricity metering box according to claim 2, characterized in that, The step of identifying whether the cable has an abnormal temperature rise based on the temperature data includes: Calculate the temperature gradient between adjacent measurement points on the cable; Determine whether the temperature at any measurement point exceeds a first preset threshold, or whether the temperature gradient between adjacent measurement points exceeds a second preset threshold; If any of the judgment conditions are met, it is determined that there is an abnormal temperature rise.

4. The fault detection method for an electricity metering box according to claim 3, characterized in that, When an abnormal temperature rise is detected, the corresponding fault warning or control command output includes: If the temperature at any measurement point exceeds the first preset threshold but does not reach the third preset threshold, or if the temperature gradient exceeds the second preset threshold, an early warning signal containing abnormal location information will be output. If the temperature at any measurement point reaches or exceeds the third preset threshold, or if the temperature change rate is detected to exceed the fourth preset threshold, a control command to cut off the incoming power supply to the power metering box will be output.

5. The fault detection method for an electricity metering box according to claim 1, characterized in that, The method further includes: Obtain the ambient temperature and humidity data inside the power metering box; The temperature data is compensated and corrected based on the ambient temperature and humidity data to eliminate interference from environmental factors causing overall temperature rise.

6. The fault detection method for an electricity metering box according to claim 1, characterized in that, The distributed optical fiber sensing system includes optical fibers disposed within or beneath a ceramic-based composite nano-coating, which is applied to the outer surface of the insulation layer of the cable and / or the inner wall of the power metering box.

7. The fault detection method for an electricity metering box according to claim 6, characterized in that, The ceramic-based composite nanocoating is configured as follows: It has a thermal conductivity higher than a preset value, which is used to efficiently conduct the heat generated by the cable to the optical fiber; It has electromagnetic shielding effectiveness lower than a preset value to avoid interference with the signal acquisition of the metering chip in the power metering box.

8. The fault detection method for an electricity metering box according to claim 4, characterized in that, While outputting the control command to cut off the incoming power supply, the method also includes: Maintain backup power supply to the metering chip inside the power metering box to ensure that metering data is not lost after power failure.

9. The fault detection method for an electricity metering box according to any one of claims 1-8, characterized in that, The method further includes: The fault warning or control command, along with the corresponding temperature data and location information, is sent to the remote operation and maintenance platform.

10. A computer device, characterized in that, It includes a processor and a memory, wherein the memory stores a computer program, and when the computer program is executed by the processor, it implements the fault detection method for the electricity metering box as described in any one of claims 1-9.

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