Power distribution network fault processing method, device, equipment, medium and product

Abstract

Embodiments of the present application provide a power distribution network fault processing method, device, equipment, medium and product. The method comprises the following steps: firstly, determining a fault area of the power distribution network according to a fault event sequence, switch position information, user power outage and restoration information and network topology of the power distribution network. Then, determining a candidate transfer path based on the fault area and the network topology. Finally, determining a target transfer path from all candidate transfer paths according to a load rate, a historical fault number, a number and a type of recoverable power supply users of each candidate transfer path. The method is used to achieve the technical effect of improving the accuracy of the transfer path.

Description

Technical Field

[0001] This application relates to the field of power equipment technology, and in particular to a method, apparatus, equipment, medium and product for handling power distribution network faults. Background Technology

[0002] Self-healing of distribution network faults and power restoration are key technologies in the field of power system operation and control. Their goal is to quickly isolate faults and restore power supply to non-faulty areas after a fault occurs, thereby improving power supply reliability. With the popularization of automated switching and communication technologies, automatic fault location, isolation, and transfer based on integrated main and distribution systems has become the mainstream technology direction in the industry.

[0003] Currently, the main method involves manually determining a general fault range based on overcurrent, grounding, and other protection signals and switch tripping information received from the main station monitoring system, combined with a pre-stored static power grid topology diagram. Subsequently, operators typically select a power transfer path from a limited number of pre-set transfer plans, based on dispatching procedures or personal experience, to ensure that the line to be transferred does not experience overload. Once the plan is selected, the dispatcher issues an operation command to execute the power transfer.

[0004] However, the accuracy of the transfer paths determined by existing methods is low. Summary of the Invention

[0005] This application provides a method, apparatus, equipment, medium, and product for handling power distribution network faults, in order to improve the accuracy of determining the transfer path.

[0006] In a first aspect, embodiments of this application provide a method for handling power distribution network faults, including:

[0007] Based on the fault event sequence, switch change information, user power outage and restoration information, and network topology of the distribution network, the fault area of ​​the distribution network is determined;

[0008] Based on the fault area and the network topology, the candidate transfer path is determined;

[0009] The target power transfer path is determined from all candidate power transfer paths based on the load rate, historical failure count, number and type of users whose power can be restored for each candidate power transfer path.

[0010] In one possible implementation, determining the target power transfer path from all candidate power transfer paths based on the load rate, historical failure count, number and type of users with recoverable power for each candidate power transfer path includes:

[0011] For each candidate power transfer path, the sub-scores corresponding to the load rate, the number of historical faults, the number of users with recoverable power supply, and the type are determined respectively;

[0012] Calculate the total score of the candidate transfer path by weighted summation of all sub-scores;

[0013] The candidate supply transfer path with the highest total score is determined as the target supply transfer path;

[0014] The load rate and the number of historical faults are negatively correlated with the corresponding sub-scores, while the number of users with recoverable power supply is positively correlated with the corresponding sub-scores. The sub-scores corresponding to the types of users with recoverable power supply, namely hospital users, school users, government users, and industrial and commercial users, are greater than the sub-scores corresponding to the types of users with recoverable power supply, namely residential users.

[0015] In one possible implementation, determining the candidate transfer path with the highest total score as the target transfer path includes:

[0016] The candidate supply transfer path with the highest total score is determined as the intermediate supply transfer path;

[0017] Power flow calculation simulation is performed on the intermediate transfer path to verify the security of the intermediate transfer path and obtain the first verification result;

[0018] If the first verification result indicates that the verification is successful, then the intermediate transfer path is determined as the target transfer path.

[0019] In one possible implementation, determining the fault area of ​​the distribution network based on the fault event sequence, switch change information, user power outage and restoration information, and network topology includes:

[0020] The fault event sequence and the switch position information are obtained from the main and distribution integrated system.

[0021] Obtain the user's power outage and restoration information from the metering automation system;

[0022] Based on the user power outage and restoration information, cross-validation is performed on the distribution network faults indicated by the fault event sequence and the switch change information to generate a second verification result;

[0023] If the second verification result indicates that the verification is successful, then the fault area of ​​the distribution network is determined based on at least one of the user power outage and restoration information, the fault event sequence, and the switch change information, as well as the network topology.

[0024] In one possible implementation, determining the candidate supply transfer path based on the fault area and the network topology includes:

[0025] On the non-faulty power supply side, identify the interconnecting switch in the network topology that is electrically adjacent to the faulty area;

[0026] For each of the aforementioned interconnecting switches, the path for supplying power to the faulty area by closing the interconnecting switch, starting from the non-faulty power supply side connected to the interconnecting switch, is determined as the candidate transfer path.

[0027] In one possible implementation, the method further includes:

[0028] Based on the fault area, generate fault inspection information;

[0029] Based on the fault inspection information, an inspection task instruction is generated, which includes the coordinates of the fault area;

[0030] The patrol task instruction is sent to the UAV inspection system so that the UAV inspection system can inspect the faulty area.

[0031] Secondly, embodiments of this application provide a power distribution network fault handling device, comprising:

[0032] The first determining module is used to determine the fault area of ​​the distribution network based on the fault event sequence, switch change information, user power outage and restoration information, and network topology.

[0033] The second determining module is used to determine the candidate transfer path based on the fault area and the network topology;

[0034] The third determination module is used to determine the target power transfer path from all candidate power transfer paths based on the load rate, historical failure count, number and type of users whose power can be restored for each candidate power transfer path.

[0035] In one possible implementation, the third determining module is specifically used for:

[0036] For each candidate power transfer path, the sub-scores corresponding to the load rate, the number of historical faults, the number of users with recoverable power supply, and the type are determined respectively;

[0037] Calculate the total score of the candidate transfer path by weighted summation of all sub-scores;

[0038] The candidate supply transfer path with the highest total score is determined as the target supply transfer path;

[0039] The load rate and the number of historical faults are negatively correlated with the corresponding sub-scores, while the number of users with recoverable power supply is positively correlated with the corresponding sub-scores. The sub-scores corresponding to the types of users with recoverable power supply, namely hospital users, school users, government users, and industrial and commercial users, are greater than the sub-scores corresponding to the types of users with recoverable power supply, namely residential users.

[0040] In one possible implementation, the third determining module is specifically used for:

[0041] The candidate supply transfer path with the highest total score is determined as the intermediate supply transfer path;

[0042] Power flow calculation simulation is performed on the intermediate transfer path to verify the security of the intermediate transfer path and obtain the first verification result;

[0043] If the first verification result indicates that the verification is successful, then the intermediate transfer path is determined as the target transfer path.

[0044] In one possible implementation, the first determining module is specifically used for:

[0045] The fault event sequence and the switch position information are obtained from the main and distribution integrated system.

[0046] Obtain the user's power outage and restoration information from the metering automation system;

[0047] Based on the user power outage and restoration information, cross-validation is performed on the distribution network faults indicated by the fault event sequence and the switch change information to generate a second verification result;

[0048] If the second verification result indicates that the verification is successful, then the fault area of ​​the distribution network is determined based on at least one of the user power outage and restoration information, the fault event sequence, and the switch change information, as well as the network topology.

[0049] In one possible implementation, the second determining module is specifically used for:

[0050] On the non-faulty power supply side, identify the interconnecting switch in the network topology that is electrically adjacent to the faulty area;

[0051] For each of the aforementioned interconnecting switches, the path for supplying power to the faulty area by closing the interconnecting switch, starting from the non-faulty power supply side connected to the interconnecting switch, is determined as the candidate transfer path.

[0052] In one possible implementation, the power distribution network fault handling device further includes:

[0053] The generation module is used to generate fault inspection information based on the fault area;

[0054] The generation module is further configured to generate an inspection task instruction based on the fault inspection information, wherein the inspection task instruction includes the coordinates of the fault area;

[0055] The sending module is used to send the patrol task instruction to the UAV inspection system so that the UAV inspection system can inspect the faulty area.

[0056] Thirdly, embodiments of this application provide an electronic device, including: a memory and a processor;

[0057] The memory stores computer-executed instructions;

[0058] The processor executes computer execution instructions stored in the memory, causing the processor to perform the first aspect and / or various possible implementations of the first aspect as described above.

[0059] Fourthly, embodiments of this application provide a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, are used to implement the first aspect and / or various possible implementations of the first aspect.

[0060] Fifthly, embodiments of this application provide a computer program product, including a computer program that, when executed by a processor, implements the first aspect and / or various possible implementations of the first aspect.

[0061] The distribution network fault handling method, apparatus, equipment, medium, and product provided in this application first integrate fault event sequences, switch change information, user power outage and restoration information, and network topology to achieve accurate and automated determination of the fault area. Then, based on the fault area and network topology, all candidate power transfer paths are generated. Finally, a comprehensive evaluation framework that simultaneously covers grid security constraints and user restoration value is constructed. The target power transfer path determined in this way is no longer merely a technically feasible solution, but a target power transfer path that proactively maximizes the social and economic benefits of power restoration while ensuring the safe operation of the distribution network. This significantly improves the comprehensive decision-making level of distribution network fault handling and increases the accuracy of the determined power transfer path. Attached Figure Description

[0062] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this application and, together with the description, serve to explain the principles of this application.

[0063] Figure 1 Flowchart of the power distribution network fault handling method provided in this application Figure 1 ;

[0064] Figure 2 Flowchart of the power distribution network fault handling method provided in this application Figure 2 ;

[0065] Figure 3A schematic diagram of the power distribution network fault handling device provided in this application;

[0066] Figure 4 A schematic diagram of the structure of the electronic device provided in this application.

[0067] The accompanying drawings illustrate specific embodiments of this application, which will be described in more detail below. These drawings and descriptions are not intended to limit the scope of the concept in any way, but rather to illustrate the concept of this application to those skilled in the art through reference to particular embodiments. Detailed Implementation

[0068] Exemplary embodiments will now be described in detail, examples of which are illustrated in the accompanying drawings. When the following description relates to the drawings, unless otherwise indicated, the same numbers in different drawings denote the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with this application. Rather, they are merely examples of apparatuses and methods consistent with some aspects of this application.

[0069] It should be noted that the user information (including but not limited to user device information, user personal information, etc.) and data (including but not limited to data used for analysis, data stored, data displayed, etc.) involved in this application are all information and data authorized by the user or fully authorized by all parties. Furthermore, the collection, use and processing of the relevant data must comply with relevant laws, regulations and standards, and corresponding operation entry points are provided for users to choose to authorize or refuse.

[0070] First, the application scenarios involved in this application will be explained:

[0071] In modern urban power grids, the distribution network directly serves millions of end users. When a fault occurs in the distribution network, the efficiency of fault handling and the quality of decision-making directly affect the stability of the power grid, the reliability of power supply to users, and socio-economic benefits.

[0072] Currently, the process mainly involves manual selection of a transfer path from a limited number of pre-set transfer plans after the fault area is identified, based on dispatching procedures or personal experience, to ensure that the line to be transferred does not become overloaded. However, this decision-making process is highly dependent on personal experience and uses the absence of line overload as the core verification criterion. It can only generate a technically feasible solution and cannot automatically optimize from multiple feasible paths, thus failing to guarantee the accuracy of the determined transfer path.

[0073] Based on the aforementioned technical problems, the technical concept of this application is as follows: During the research on power transfer schemes for distribution network faults, the inventors discovered that the dimensions of manual judgment in existing methods are relatively singular. However, for users within the fault's impact range, their number and type directly determine the socio-economic value created by power restoration. Therefore, the inventors considered integrating fault event sequences, switch change information, user power outage and restoration information with network topology to first determine the fault area and all candidate power transfer paths. Then, the number and type of users whose power supply can be restored—a dimension directly reflecting restoration efficiency—are integrated with technical safety dimensions such as load factor and historical fault frequency for comprehensive evaluation. This forms a power transfer decision-making scheme that can simultaneously consider grid operation safety and power restoration value, thereby improving the accuracy of the determined power transfer paths.

[0074] The technical solution of this application and how the technical solution of this application solves the above-mentioned technical problems are described in detail below with specific embodiments. These specific embodiments can be combined with each other, and the same or similar concepts or processes may not be described again in some embodiments. The embodiments of this application will now be described with reference to the accompanying drawings.

[0075] Figure 1 Flowchart of the power distribution network fault handling method provided in this application Figure 1 ,like Figure 1 As shown, the method includes:

[0076] S11. Based on the fault event sequence, switch change information, user power outage and restoration information, and network topology of the distribution network, determine the fault area of ​​the distribution network.

[0077] Among them, the fault event sequence refers to a series of equipment actions and state changes recorded in chronological order, reflecting the complete process of fault occurrence, development and protection device operation.

[0078] For example, the fault event sequence is as follows: 14:30:01, the overcurrent protection stage I of line L101 is activated; 14:30:02, the circuit breaker CB101 trips; 14:30:03, the fault recorder is triggered.

[0079] In practical applications, there are also situations where communication interruptions in the main and distribution integrated system lead to delayed reporting or partial loss of fault event sequences and switch position information. In this scenario, it is necessary to supplement the judgment by combining user power outage and restoration information provided by the metering automation system.

[0080] For example, if the metering automation system detects a large-scale power outage in a certain area, but the main distribution system fails to report the corresponding fault event sequence within a preset time, a data anomaly alarm is triggered. The system uses user power outage and restoration information as the sole data source for fault location, combining this with network topology to infer the fault area. Simultaneously, it continuously monitors the data recovery status of the main distribution system, automatically supplementing the fault event sequence and updating the fault location results once the data returns to normal.

[0081] When obtaining fault event sequences and switch change information from the integrated main and distribution system, data subscription and real-time push can be performed through standardized communication protocols. Fault event sequences are typically transmitted in a time-stamped event sequence record format, with each record containing information such as equipment identifier, event type, and event occurrence time. Switch change information is typically transmitted in a remote signaling change format, with each record containing information such as switch equipment identifier, the open / closed state after the change, and the change time. When obtaining user power outage and restoration information from the metering automation system, user power outage and restoration information is typically summarized and reported by transformer area or user, including metering point identifier, the occurrence time of the power outage event, and the restoration time.

[0082] Among them, switch change information refers to event signals in which the opening or closing status of equipment such as circuit breakers, load switches, and disconnect switches in the distribution network changes.

[0083] For example, the switch change information is: a fault causes the circuit breaker at the beginning of the line to change from closed to open, or a downstream section switch trips due to protection action.

[0084] Network topology refers to a model that describes all electrical equipment (such as substations, switches, lines, and transformers) and their connections in a power distribution network. It is used to explain the upstream and downstream relationships of each line, the location of tie switches, and the distribution of power sources.

[0085] Among them, user power outage and restoration information reflects real-time information on the interruption and restoration of user power supply status. In practical applications, user power outage and restoration information includes power outage information and power restoration information.

[0086] For example, if a large number of smart meters in a certain area are detected to have lost voltage or dropped to zero current after a fault, a power outage message is generated; when power is restored and the meter voltage returns to normal, a power restoration message is generated.

[0087] In one possible implementation, fault event sequences and switch change information are obtained from the integrated main and distribution system, and user power outage and restoration information is obtained from the metering automation system. Then, based on the user power outage and restoration information, cross-validation is performed on the distribution network faults indicated by the fault event sequences and switch change information to generate a second validation result. If the second validation result indicates successful validation, the fault area of ​​the distribution network is determined based on at least one of the user power outage and restoration information, the fault event sequence, and the switch change information, as well as the network topology.

[0088] Among them, the main and distribution integrated system refers to a centralized automation system that integrates the monitoring of the main grid and the distribution network operation status. It is the real-time information hub for grid dispatch and operation, and is responsible for collecting electrical quantity measurements (telemetry) and status signals (telecommunications) of various equipment in substations and switching stations.

[0089] Metering automation systems refer to a network of systems used for remote automatic reading and monitoring of smart meter data on the user side. It covers the end of the distribution network and serves as a channel for sensing the power supply status of users.

[0090] Specifically, the system synchronously retrieves fault event sequences describing equipment actions and switch position information from the integrated main and distribution system, and user power outage and restoration information reflecting user power supply status from the metering automation system. Then, it uses the user power outage and restoration information to verify whether the faults reported by the fault event sequences and switch position information actually caused large-scale user power outages, thus filtering false alarms or locating data anomalies. For example, if a circuit breaker trip signal is received, but all downstream user meters on the same line simultaneously show normal power supply, a second verification result indicating an anomaly will be generated. If the second verification result indicates successful verification, the precise range of the fault, i.e., the fault area, can be calculated using topology inference algorithms (such as logic analysis based on switching functions).

[0091] It is understandable that cross-validation is a two-way verification. On the one hand, if a circuit breaker trip signal is received, but at the same time all downstream user meters show normal power supply, a second verification result indicating an anomaly will be generated. On the other hand, if the metering automation system detects a large-scale power outage in a certain area, but the main distribution system does not report the corresponding fault event sequence, a second verification result indicating an anomaly will also be generated, triggering a data anomaly alarm to prevent protection signals from being missed and faults from being overlooked.

[0092] Understandably, logic analysis based on switching functions refers to gradually narrowing down the smallest isolation section where a fault may occur, based on the tripping status signals of circuit breakers and sectionalizing switches, combined with the upstream and downstream connections between switches in the network topology.

[0093] For example, if the circuit breaker at the beginning of the line trips, but a fault current is not detected at a downstream sectionalizing switch, it can be presumed that the fault is located in the section between the circuit breaker and the sectionalizing switch.

[0094] Optionally, if the verification fails, a data anomaly alarm will be output to ensure data reliability.

[0095] The above implementation effectively filters out false fault signals caused by single system false alarms or communication interference, and the location analysis is only initiated after the second verification result is passed. Based on reliable data verified by multiple sources, and combined with network topology for fault location, the determined fault area is not only accurate but also highly reliable, providing a solid and error-free data foundation for subsequent transfer path generation and decision-making, thus improving the robustness of the entire processing flow from the source.

[0096] Optionally, a route map containing highlighted faulty sections can be generated based on the faulty area. For example, a map can be obtained from a Geographic Information System (GIS), and the faulty area can be highlighted in green to generate a route map.

[0097] S12. Based on the fault area and network topology, determine the candidate transfer path.

[0098] In one possible implementation, on the non-faulty power supply side, the tie switches electrically adjacent to the faulty area in the network topology are identified. For each tie switch, the path for supplying power to the faulty area through closing the tie switch, starting from the non-faulty power supply side connected to the tie switch, is determined as the candidate transfer path.

[0099] Among them, the non-faulty power supply side refers to the line or power supply feeder section in the distribution network that is not affected by this fault event and still maintains a normal power supply status. The feeder refers to the distribution line that leads out from the substation bus to supply power to the load, and is the main power supply channel connecting the substation and the user in the distribution network.

[0100] For example, if a fault occurs on 10 kV line A, which is supplied by substation A, then 10 kV line B, which is supplied by substation B and is operating normally, is a non-faulty power supply side.

[0101] Electrically adjacent tie switches refer to switching devices in the network topology model whose installation location has a direct electrical connection to both the faulty area and a non-faulty power supply side. These switches are usually in the open state during normal operation to isolate feeders from different power sources, but can be closed to connect the two parts during power transfer operations.

[0102] For example, in a distribution network, tie switches are often in the open state during normal operation, and their location information is stored in the network topology model. By traversing all switching devices on the boundary of the fault area in the network topology, switches that are currently in the open state and have an electrical connection with both the fault area and the non-faulty power supply side are selected and identified as electrically adjacent tie switches.

[0103] For example, a tie switch may be installed at the junction of line A (current fault) and line B (non-fault power supply side), with one side connected to the end of line A (belonging to the fault area boundary) and the other side connected to a segment point of line B (belonging to the non-fault power supply side).

[0104] In actual power distribution networks, there may be multiple electrically adjacent tie switches at the boundary of a fault area. For example, a fault area may be connected to line L2 through tie switch K1, line L3 through tie switch K2, and line L4 through tie switch K3. In this case, three different candidate transfer paths will be generated, each path corresponding to a tie switch, and they will be evaluated separately in the subsequent multi-factor scoring process.

[0105] Furthermore, in actual operation, there may be scenarios where the tie switch cannot be remotely controlled due to maintenance, interlocking, or other reasons. In such cases, the tie switch needs to be excluded when generating candidate power transfer paths, or the candidate power transfer path corresponding to the tie switch needs to be marked as unavailable, and corresponding prompts should be output after the final score ranking.

[0106] A tie switch is a switching device installed between two feeders to enable flexible adjustment of the operation mode of the distribution network and load transfer after a fault.

[0107] Specifically, all tie switches electrically adjacent to the faulty area are identified in the network topology. Each tie switch in the open state represents a potential path connecting to another healthy line (i.e., the non-faulty power supply side). For each such tie switch, a complete path is generated, starting from the power supply side of the healthy line connected to the tie switch, to deliver power to the faulty area by closing the tie switch; this path is then identified as a candidate power transfer path.

[0108] For example, if there is a tie switch K1 upstream of the fault area connected to line L2, the generated candidate power transfer path is: the path from the power source of L2, through closed K1, to supply power to the fault area.

[0109] The above implementation method ensures the comprehensiveness of the generated solutions, avoiding the omission of potential high-quality paths due to limitations in human experience. Meanwhile, the path definition, starting from the non-faulty power supply side, with the closing of the tie switch as the key operation, and the supply of power to the faulty area as the goal, accurately reflects the physical nature and operational reality of power transfer in the distribution network. This ensures that each solution in the generated set of candidate power transfer paths has clear operational meaning and engineering feasibility.

[0110] S13. Based on the load rate, historical failure count, number and type of users whose power supply can be restored for each candidate power transfer path, determine the target power transfer path from all candidate power transfer paths.

[0111] The load factor refers to the existing load level of the healthy lines on which the candidate transfer path depends before taking on new load, and is usually expressed as a percentage.

[0112] For example, if a line is currently receiving 70% of its rated current carrying capacity, then its load factor is 70%.

[0113] Among them, the number of historical failures refers to the number of times that the healthy lines on which the candidate supply path depends have failed within a past statistical period.

[0114] It should be understood that the statistical period in the past could be a week, a month, a year, etc., which can be specifically determined according to the actual situation. This application does not impose specific restrictions on this.

[0115] The number of users whose power supply can be restored refers to the total number of users whose normal power supply is expected to be restored after a certain alternative power transfer path is implemented. This number is obtained by analyzing the statistics of all user metering points within the downstream power supply range of the path.

[0116] The types of users whose power can be restored refer to the social attribute classification of the aforementioned users, such as hospitals, schools, government agencies, industrial and commercial users, and residential users.

[0117] In one possible implementation, for each candidate power transfer path, sub-scores are determined for four factors: load factor, number of historical failures, number of users with recoverable power, and power type. Then, all sub-scores are weighted and summed to calculate the total score for the candidate power transfer path. Finally, the candidate power transfer path with the highest total score is determined as the target power transfer path.

[0118] It should be understood that the specific implementation process and principles of this method will be explained later. Figure 2 The embodiments shown are described in detail here, and will not be repeated here.

[0119] The distribution network fault handling method provided in this application first determines the fault area of ​​the distribution network based on the fault event sequence, switch change information, user power outage and restoration information, and network topology. Then, based on the fault area and network topology, candidate power transfer paths are determined. Finally, based on the load rate, historical fault count, number and type of users whose power can be restored for each candidate power transfer path, the target power transfer path is determined from all candidate power transfer paths. In this technical solution, fault event sequences, switch change information, user power outage and restoration information, and network topology are first integrated to achieve accurate and automated determination of the fault area. Then, based on the fault area and network topology, all candidate power transfer paths are generated. Finally, a comprehensive evaluation framework that simultaneously covers grid security constraints and user restoration value is constructed. The target power transfer path determined in this way is no longer merely a technically feasible solution, but a target power transfer path that can proactively maximize the social and economic benefits of power restoration while ensuring the safe operation of the distribution network. This significantly improves the comprehensive decision-making level of distribution network fault handling and increases the accuracy of the determined power transfer path.

[0120] Optionally, in some embodiments, the power outage range, the number of affected users, and the location information of the affected users can also be dynamically displayed on the emergency command screen based on a geographic information system.

[0121] On the emergency command screen, the power outage area is marked with different colors, the number of affected users is displayed in the form of a heat map, and the location information of affected users is marked as points on a geographic information system map. Through this visualization, emergency command personnel can grasp the overall impact of the power outage in real time and intuitively, and accurately guide the allocation of emergency resources.

[0122] Optionally, in some embodiments, fault data of the distribution network can also be stored, and a list of equipment experiencing repeated power outages can be generated based on historical fault data. The list of equipment experiencing repeated power outages includes equipment identifiers, fault occurrence times, and corresponding fault areas that have occurred more than a preset number of times within a preset time period. The list of equipment experiencing repeated power outages is used for power grid renovation project analysis, providing data support for precise investment and the improvement of weak links in the distribution network.

[0123] Figure 2 Flowchart of the power distribution network fault handling method provided in this application Figure 2 ,like Figure 2 As shown, S13 includes:

[0124] S21. For each candidate power transfer path, determine the load rate, number of historical faults, number of users whose power can be restored, and the sub-scores corresponding to the four factors.

[0125] The sub-score corresponding to the load factor is a score calculated based on the current load factor of the healthy lines on which the candidate supply transfer path depends. This sub-score aims to reflect the short-term safety margin of the path; the lower the load factor, the greater the capacity of the line to accommodate new loads, and the corresponding sub-score should generally be set higher.

[0126] For example, if the linear normalization method is used, a line with a load factor of 30% will have a sub-score of 0.9 (out of 1.0); while a line with a load factor of 85% will have a sub-score of 0.15.

[0127] It's important to understand that the calculation methods for the sub-scores in the above dimensions are not limited to linear normalization. In practical applications, other calculation methods can be selected based on specific needs. For example, for load factor, a piecewise function can be used: when the load factor is below 50%, the sub-score is the full score of 1.0; when the load factor is between 50% and 80%, the sub-score decreases linearly; and when the load factor is above 80%, the sub-score is 0. This piecewise function method can more accurately reflect the differences in safety margins of the line under different load levels. As another example, for the number of historical faults, an exponential decay method can be used to set the sub-score, allowing lines with fewer historical faults to receive higher scores while avoiding a significant drop in score due to a single, isolated fault.

[0128] The sub-score corresponding to the number of historical failures is a score calculated based on the number of historical failures of the healthy lines on which the candidate supply route depends. This sub-score aims to reflect the long-term operational reliability of the facilities on which the route depends; the fewer the number of historical failures, the more stable and reliable the line is, and the corresponding sub-score should generally be set higher.

[0129] For example, a line that experienced one failure in the past year might have a sub-score of 0.8, while a line that experienced five failures might have a sub-score of 0.2.

[0130] The sub-score corresponding to the number of users whose power can be restored is a score calculated based on the number of households whose power can be restored after implementing the candidate power transfer path. This sub-score directly measures the scale benefit of the power restoration scheme; the larger the number of users whose power can be restored, the more users can benefit from the scheme, and the higher the corresponding sub-score should be.

[0131] Optionally, the number of users whose power supply can be restored is determined by the following method: based on the network topology within the downstream power supply range of the candidate power transfer path, the number of all user metering points within the downstream power supply range of the path is counted, and the counted number of user metering points is determined as the number of users whose power supply can be restored.

[0132] For example, if 1,000 households can be restored, its sub-score is 1.0; if 300 households can be restored, its sub-score may be 0.3.

[0133] Among them, the sub-score corresponding to the type of user with recoverable power supply refers to the score value calculated based on the social attributes corresponding to the type of user with recoverable power supply. Different social attributes correspond to different degrees of urgency for power restoration, and user types with higher degrees of urgency for power restoration should contribute higher sub-scores.

[0134] Among them, the types of users whose power can be restored include important users and ordinary users. Important users include hospital users, school users, government users, and industrial and commercial users, while ordinary users include residential users. The important user weights are pre-configured, and when the important user weights are used to calculate the sub-scores corresponding to the types of users whose power can be restored, the sub-scores of important users are greater than the sub-scores of ordinary users.

[0135] For example, the sub-score for hospital users is 0.6; the sub-score for resident users is 0.2; and the sub-score for industrial and commercial users (commercial districts) is 0.5.

[0136] In other words, the load factor and the number of historical faults are negatively correlated with the corresponding sub-scores, while the number of users with recoverable power supply is positively correlated with the corresponding sub-scores. The sub-scores corresponding to users with recoverable power supply who are hospital users, school users, government users, and industrial and commercial users are greater than the sub-scores corresponding to users with recoverable power supply who are residential users.

[0137] S22. Calculate the total score of the candidate transfer paths by weighted summation of all sub-scores.

[0138] In one possible implementation, a weight coefficient is assigned to each of the four dimensions (load rate, number of historical failures, number of users with recoverable power, and type), and the sum of all weight coefficients is typically 1. The sub-scores corresponding to the load rate, number of historical failures, number of users with recoverable power, and type are multiplied by their respective weight coefficients, and then the four products are added together. The sum is then used to determine the total score.

[0139] It should be understood that the above weighting coefficients can be preset based on empirical or experimental values, and this application embodiment does not impose specific restrictions on this.

[0140] For example, when the business strategy prioritizes ensuring people's livelihood, the weighting coefficients corresponding to the types of users with recoverable power supply and the number of users with recoverable power supply can be set higher; when the business strategy prioritizes ensuring grid security, the weighting coefficients corresponding to the load rate and the number of historical faults can be set higher. This configurable weighting coefficient setting method allows the decision-making model to flexibly adapt to the differentiated power supply guarantee strategies of different regions.

[0141] In practical applications, the weighting coefficients can be dynamically adjusted based on seasonal characteristics or power supply security needs during special periods. For example, during peak summer electricity consumption, grid equipment load rates are generally high. In this case, the weighting coefficient corresponding to the load rate can be increased to prioritize grid operational safety and prevent equipment overload caused by power transfer operations. During major events, the weighting coefficients corresponding to important user types can be adjusted to the highest level to ensure the power supply reliability of important users such as event venues and support units. This dynamically configurable weighting coefficient mechanism allows the decision-making model to flexibly adapt to power supply security needs in different scenarios, improving the targeting and effectiveness of power transfer decisions.

[0142] S23. The candidate supply path with the highest total score is determined as the target supply path.

[0143] In one possible implementation, if the total score of path A is 0.85, path B is 0.66, and path C is 0.72, then path A is determined as the target transfer path.

[0144] In another possible implementation, the candidate supply transfer path with the highest total score is determined as the intermediate supply transfer path. Then, power flow calculation simulation is performed on the intermediate supply transfer path to verify its safety, obtaining a first verification result. If the first verification result indicates that the verification passed, the intermediate supply transfer path is determined as the target supply transfer path.

[0145] Among them, power flow calculation simulation refers to the process of using computer software to calculate the voltage of each node, the current and power distribution of each branch under the steady-state operation of the power grid, based on the network topology, equipment parameters, load distribution and planned operations (such as closing the tie switch in the intermediate transfer path).

[0146] Specifically, using the current real-time state of the power grid as initial conditions, the connection relationships corresponding to intermediate power transfer paths in the network topology model are modified. This involves simulating the closure of key tie switches along these paths in the digital model, thus forming a power grid model representing the new operating mode after power transfer. Subsequently, a power flow simulation program is called to solve this new model. After the calculation is complete, all key parameters in the simulation results are automatically checked, especially the load rate of the lines involved in the intermediate power transfer path after power transfer and the voltage values ​​of relevant nodes, and compared with safety thresholds. Based on the comparison results, a clear first verification result is generated.

[0147] For example, if simulation calculations show that the line load reaches 98% after the power transfer, exceeding the safety limit of 95%, then the first verification result is a failure.

[0148] If the first verification result indicates that the verification fails, the intermediate transfer path is excluded, and the candidate transfer path with the second highest total score is selected as the new intermediate transfer path. Power flow calculation simulation is then performed on this new intermediate transfer path. This process is repeated until an intermediate transfer path that passes the security verification is determined and designated as the target transfer path. If all candidate transfer paths fail the security verification, an alarm message is output, indicating the need for manual intervention or a non-standard transfer solution. Simultaneously, all candidate transfer paths, their total score ranking, and the reasons for verification failure are output for dispatchers' reference and decision-making.

[0149] In the above implementation, the path with the highest total score is first identified as the intermediate transfer path, and its safety is verified through power flow calculation simulation. This effectively prevents potential operational risks caused by model simplification or data deviation. Only when the first verification result indicates that the intermediate transfer path has passed is it finally determined as the target transfer path. This ensures that the determined optimal solution not only scores the highest in the evaluation model but is also absolutely safe and reliable under the real physical constraints of the power grid. It eliminates the possibility of secondary faults such as line overload caused by the transfer operation, greatly enhancing the reliability and practicality of the entire intelligent decision-making system.

[0150] In the above implementation, the negative correlation between load rate, historical fault count, and sub-score was clarified, as was the positive correlation between the number of users with recoverable power and sub-score. Quantitative definitions were also made for the priority of different user types. This design transforms complex, multi-dimensional, and multi-objective decisions into objective mathematical calculations, ensuring the standardization and repeatability of the decision-making process. Furthermore, through the configuration of weighting coefficients, it can flexibly adapt to differentiated power supply guarantee strategies in different regions and at different times, making the solution highly adjustable while maximizing user benefits.

[0151] Optionally, in some embodiments, fault inspection information can be generated based on the fault area. Then, based on the fault inspection information, an inspection task instruction is generated, which includes the coordinates of the fault area. The inspection task instruction is then sent to the UAV inspection system so that the UAV inspection system can inspect the fault area.

[0152] Among them, fault inspection information refers to a structured set of data derived from the fault area to guide inspection operations. It includes the core elements required to perform the inspection, such as the identification of the faulty equipment / line, the name of the line to which it belongs, the preset inspection points, and the coordinates of the fault area.

[0153] The inspection mission instruction refers to a standardized digital command that can be directly recognized and executed by the UAV inspection system. This inspection mission instruction is transformed and encapsulated from fault inspection information and includes locationable geographic information, namely the coordinates of the fault area.

[0154] It should be understood that the inspection task instructions are automatically generated without human intervention. After the fault area is determined, the system automatically extracts the coordinate information and equipment information corresponding to the fault area from the geographic information system and the ledger system, and automatically encapsulates and generates inspection task instructions according to the preset instruction template. These instructions are then sent directly to the UAV inspection system through an interface, realizing full automation from fault location to inspection task issuance.

[0155] Among them, the unmanned aerial vehicle (UAV) inspection system refers to an intelligent operation system consisting of UAVs, airports (nests), communication links and ground control stations, which can receive remote task commands and autonomously or semi-autonomously perform power line inspection tasks.

[0156] Specifically, based on the identified fault area, the system determines the corresponding equipment register, route, and precise geographical coordinates of key towers, assembling a structured fault inspection report. Then, following a pre-agreed data interface protocol with the UAV inspection system, the key content of the fault inspection report (especially the coordinates of the fault area) is encapsulated into a specific instruction format, generating an executable inspection task instruction. Finally, the system calls the Application Programming Interface (API) to send the inspection task instruction to the UAV inspection system's control platform. After receiving and parsing the instruction, the UAV inspection system automatically plans its flight path, dispatches the UAV to the location indicated by the fault area's coordinates to perform detailed inspections, such as taking photos or measuring temperature, and transmits the results back.

[0157] It should be understood that inspection work orders can be created in the production management system, and the work orders and the coordinates of the fault areas can be transmitted to the UAV inspection system via API interface.

[0158] In the above embodiments, a patrol task instruction containing precise coordinates is generated based on the fault area and automatically sent to the UAV inspection system. This allows on-site fault location work to be initiated simultaneously and accurately while intelligent power transfer decisions are made to restore power. This changes the traditional model where fault location relies on manual labor and has a slow response time, achieving precise positioning and automatic patrol flights, greatly shortening the physical repair time and improving operation and maintenance efficiency.

[0159] Optionally, fault area information, wiring diagrams, and target transfer routes can also be pushed to designated maintenance terminals. For example, fault area information, wiring diagrams, and target transfer routes can be packaged and pushed to the maintenance personnel's application (APP).

[0160] Based on the above embodiments, specific examples will be used to explain the power distribution network fault handling method provided in this application.

[0161] Taking power transfer decision-making as an example, the following two candidate power transfer paths are generated:

[0162] Option A: Lower technical security (higher load rate, 85%), but extremely high user benefits (can restore power to 900 households and a major hospital).

[0163] Option B: High technical security (low load rate, 60%), but low user benefits (only 300 ordinary business users are restored, no important users).

[0164] The four evaluation factors (load rate, number of historical failures, number and type of users with recoverable power) are normalized and assigned different weight coefficients to obtain the total score for each candidate power transfer path.

[0165] Specifically, the total score can be calculated using the following formula:

[0166] S=w l f(L)+w f f(F)+w n f(N)+w i f(I)

[0167] Among them, w l w f w n w i These represent the weighting coefficients for load factor, historical failure count, number of recoverable power users, and type of recoverable power users, respectively, and w l +w f +w n +w i =1; S is the total score; f() is the normalization function, used to unify all factors to the same dimension (between 0 and 1).

[0168] Next, we will explain the four factors in detail: load factor, number of historical faults, number of users with recoverable power supply, and type of users with recoverable power supply.

[0169] Load factor f(L): The larger the value, the better, so f(L) = 1 - load factor is adopted.

[0170] Candidate supply transfer path A: f(L) = 1 - 0.85 = 0.15;

[0171] Candidate supply route B: f(L) = 1 - 0.60 = 0.40;

[0172] Historical failure frequency factor f(F): The larger the value, the better. Therefore, f(F) = 1 - historical failure frequency (normalized value) is adopted.

[0173] Candidate supply transfer path A: f(F) = 1 - 0.1 = 0.90;

[0174] Candidate supply route B: f(F) = 1 - 0.3 = 0.70;

[0175] The number of users with recoverable power supply, factor f(N): the larger the value, the better. The normalized value is used directly.

[0176] Candidate supply transfer path A: f(N) = 0.90;

[0177] Candidate supply route B: f(N) = 0.30;

[0178] Important user weight factor f(I): The larger the value, the better. The normalized value is used directly.

[0179] Candidate supply path A: f(I) = 1.00;

[0180] Candidate supply transfer path B: f(I) = 0.10;

[0181] Assume w l =0.2, w f =0.1、w n =0.3、w i =0.4 represents the weighting coefficients for load rate, number of historical faults, number of users with recoverable power supply, and type of users with recoverable power supply, respectively.

[0182] Therefore, the total score for candidate supply path A is calculated as follows:

[0183] S A =(0.2×0.15)+(0.1×0.90)+(0.3×0.90)+(0.4×1.00)

[0184] =0.03+0.09+0.27+0.40

[0185] =0.900

[0186] The total score for candidate supply path B is:

[0187] S B =(0.2×0.40)+(0.1×0.70)+(0.3×0.30)+(0.4×0.10)

[0188] =0.08+0.07+0.09+0.04

[0189] =0.412

[0190] In other words, the calculated comprehensive score for candidate power transfer path A is 0.900, while that for candidate power transfer path B is 0.412. Although candidate power transfer path A has a higher line load rate, its significant advantage in user benefits (restoring a large number of residents and critical medical units) makes its comprehensive score much higher than that of candidate power transfer path B. Therefore, candidate power transfer path A is determined as the intermediate power transfer path, and after verifying its safety through power flow calculation simulation, the intermediate power transfer path is determined as the target power transfer path.

[0191] This demonstrates that the application can effectively balance technical constraints and business needs, maximizing the socio-economic benefits of fault recovery while ensuring power grid safety.

[0192] It is important to understand that distribution networks operate under various special conditions in practice. For example, during fault repair or planned power outages, some lines may be in a temporary connection state, resulting in a network topology different from normal operation. In this scenario, before implementing the distribution network fault handling method provided in this application, it is necessary to obtain the latest topology information from the network topology model to ensure that the fault area determination and the generation of candidate power transfer paths are based on the latest network topology. Furthermore, in distribution networks with a large number of distributed generation sources, some lines may experience reverse power flow. Power flow calculation simulations need to incorporate the output of distributed generation sources into the calculation model to ensure that the simulation results accurately reflect the grid operation state after power transfer.

[0193] Furthermore, some distribution networks may experience complex scenarios where multiple faults occur simultaneously. In such scenarios, the method provided in this application can be executed separately for each fault to independently determine the fault area and target power transfer path corresponding to each fault. If the candidate power transfer paths corresponding to different faults overlap or influence each other, multiple power transfer operations will be combined for joint simulation verification during the power flow calculation simulation stage to ensure that the simultaneous execution of multiple power transfer schemes does not lead to risks to the safety of power grid operation.

[0194] In summary, compared with existing technologies, the power distribution network fault handling method provided in this application achieves closed-loop management of the entire process from fault occurrence to power restoration, bringing significant technical and business advantages, specifically reflected in:

[0195] 1. Optimization of decision-making dimensions: from single security considerations to multi-factor comprehensive optimization.

[0196] This application achieves a fundamental leap in decision-making logic by quantifying the number of users with recoverable power and the weight of important users as core decision factors, and placing them on an equal footing with traditional technical factors such as load factor and historical failure frequency for comprehensive evaluation. This transforms the generation and selection of power transfer applications from merely pursuing technical feasibility (such as avoiding overload) to pursuing comprehensive optimization, that is, maximizing the social and economic benefits of power restoration while strictly ensuring the safe operation of the power grid. Its value lies in its ability to automatically prioritize the restoration of power to important users such as hospitals, government agencies, and large numbers of residents based on preset strategies (such as prioritizing people's livelihoods), significantly improving power supply reliability and user satisfaction.

[0197] 2. Qualitative change in operation and maintenance processes: from manual sequential processing to fully automated processes.

[0198] This application achieves a closed-loop automation of the entire process, from multi-source data triggering, precise fault location and mapping, intelligent transfer decision-making and verification, to information synchronization and task distribution. It automatically completes core steps such as cross-validation of fault information, generation and scoring of candidate transfer paths, power flow calculation simulation safety verification, and pushing the target transfer path to the operation and maintenance terminal. Its value lies in freeing operation and maintenance personnel from tedious information processing, communication and coordination, and experience-based decision-making, significantly shortening the average fault repair time, fundamentally improving operation and maintenance efficiency, and allowing personnel to focus more on necessary on-site operations.

[0199] 3. Transformation of Inspection Mode: From Manual Experience-Based Inspection to Coordinate-Driven Precision Inspection

[0200] This application, through an automated inspection triggering step, can automatically generate inspection task instructions containing precise geographic coordinates based on fault area information and directly issue them to the UAV inspection system. Its value lies in automating and increasing the precision of fault location operations, enabling UAVs to automatically fly to the coordinates of the fault area for detailed inspection, completely changing the traditional model of relying on manual inspection along the route. This greatly improves the efficiency of fault location, is particularly suitable for complex environments, and reduces the safety risks for personnel working on-site.

[0201] 4. Upgrading of Command Support: From Dispersed Information to Panoramic Fusion Visualization

[0202] This application utilizes a panoramic visualization module to dynamically integrate multi-dimensional information such as power outage areas, user impact heat maps, and the location of emergency resources onto an emergency command screen based on a geographic information system. Its value lies in providing a real-time, intuitive, and comprehensive panoramic view for command and decision-making, breaking down the previous siloed state of various information systems, and making decision-making processes such as fault impact assessment, emergency repair resource allocation, and external information dissemination more scientific and efficient.

[0203] 5. Advancements in Power Grid Governance: From Experience-Based Judgment to Data-Driven Precision Governance

[0204] This application possesses comprehensive fault data recording and analysis capabilities, enabling it to automatically generate in-depth analysis reports, such as lists of equipment experiencing recurring power outages, based on historical data. Its value lies in transforming data generated during fault handling into valuable assets, providing objective and quantitative data support for precise investment in distribution networks, the upgrading of weak links, and network optimization. This drives the evolution of power grid planning and governance from an experience-driven to a data-driven scientific model.

[0205] Figure 3 This is a schematic diagram of the structure of the power distribution network fault handling device provided in this application, as shown below. Figure 3 As shown, the power distribution network fault handling device 30 provided in this embodiment includes:

[0206] The first determining module 301 is used to determine the fault area of ​​the distribution network based on the fault event sequence, switch change information, user power outage and restoration information and network topology.

[0207] The second determining module 302 is used to determine the candidate transfer path based on the fault area and network topology.

[0208] The third determining module 303 is used to determine the target power transfer path from all candidate power transfer paths based on the load rate, historical fault count, number and type of users whose power supply can be restored for each candidate power transfer path.

[0209] In one possible implementation, the third determining module 303 is specifically used for:

[0210] For each candidate power transfer path, the load rate, number of historical faults, number of users with recoverable power, and the sub-scores corresponding to the four factors are determined.

[0211] The total score of the candidate supply routes is calculated by weighted summation of all sub-scores.

[0212] The candidate supply transfer path with the highest total score is selected as the target supply transfer path.

[0213] Among them, the load rate and the number of historical faults are negatively correlated with the corresponding sub-scores, while the number of users with recoverable power supply is positively correlated with the corresponding sub-scores. The sub-scores corresponding to the types of users with recoverable power supply, namely hospital users, school users, government users, and industrial and commercial users, are greater than the sub-scores corresponding to the types of users with recoverable power supply, namely residential users.

[0214] In one possible implementation, the third determining module 303 is specifically used for:

[0215] The candidate supply transfer path with the highest total score is selected as the intermediate supply transfer path.

[0216] Power flow calculation simulation was performed on the intermediate supply transfer path to verify its security, and the first verification result was obtained.

[0217] If the first verification result indicates that the verification is successful, then the intermediate transfer path will be determined as the target transfer path.

[0218] In one possible implementation, the first determining module 301 is specifically used for:

[0219] Obtain fault event sequences and switch position information from the main and distribution integrated system.

[0220] Obtain user power outage and restoration information from the metering automation system.

[0221] Based on user power outage and restoration information, cross-validation is performed on the distribution network faults indicated by fault event sequences and switch change information to generate a second verification result.

[0222] If the second verification result indicates that the verification is successful, the fault area of ​​the distribution network is determined based on at least one of the following: user power outage and restoration information, fault event sequence, and switch change information, as well as the network topology.

[0223] In one possible implementation, the second determining module 302 is specifically used for:

[0224] On the non-faulty power supply side, identify the interconnecting switch in the network topology that is electrically adjacent to the faulty area.

[0225] For each tie switch, the path from the non-faulty power supply side connected to the tie switch to the faulty area through the closed tie switch will be determined as the candidate transfer path.

[0226] In one possible implementation, the power distribution network fault handling device 30 further includes:

[0227] The generation module is used to generate fault inspection information based on the fault area.

[0228] The generation module is also used to generate inspection task instructions based on the fault inspection information. The inspection task instructions include the coordinates of the fault area.

[0229] The sending module is used to send patrol task instructions to the UAV inspection system so that the UAV inspection system can inspect the faulty area.

[0230] The power distribution network fault handling device provided in this embodiment can execute the method provided in the above method embodiment. Its implementation principle and technical effect are similar, and will not be described in detail here.

[0231] Figure 4A schematic diagram of the structure of the electronic device provided in this application. Figure 4 As shown, the electronic device 40 provided in this embodiment includes at least one processor 401 and a memory 402. Optionally, the electronic device 40 further includes a communication component 403. The processor 401, memory 402, and communication component 403 are connected via a bus 404.

[0232] In a specific implementation, at least one processor 401 executes computer execution instructions stored in memory 402, causing at least one processor 401 to perform the above-described method.

[0233] The specific implementation process of processor 401 can be found in the above method embodiments, and its implementation principle and technical effect are similar. It will not be repeated here.

[0234] In the above embodiments, it should be understood that the processor can be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), etc. The general-purpose processor can be a microprocessor or any conventional processor. The steps of the method disclosed in this invention can be executed by a hardware processor, or by a combination of hardware and software modules within the processor.

[0235] The memory may include random access memory (RAM) and may also include non-volatile memory (NVM), such as at least one disk storage device.

[0236] The bus can be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, or an Extended Industry Standard Architecture (EISA) bus, etc. Buses can be categorized as address buses, data buses, control buses, etc. For ease of illustration, the buses shown in the accompanying drawings are not limited to a single bus or a single type of bus.

[0237] This application also provides a computer program product, including a computer program that, when executed by a processor, implements the above-described method.

[0238] This application also provides a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, implement the above-described method.

[0239] The aforementioned readable storage medium can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as Static Random-Access Memory (SRAM), Electrically Erasable Programmable Read-Only Memory (EEPROM), Erasable Programmable Read-Only Memory (EPROM), Programmable Read-Only Memory (PROM), Read-Only Memory (ROM), magnetic storage, flash memory, magnetic disk, or optical disk. The readable storage medium can be any available medium accessible to a general-purpose or special-purpose computer.

[0240] An exemplary readable storage medium is coupled to a processor, enabling the processor to read information from and write information to the readable storage medium. Of course, the readable storage medium can also be a component of the processor. The processor and the readable storage medium can reside in an application-specific integrated circuit (ASIC). Alternatively, the processor and the readable storage medium can exist as discrete components in the device.

[0241] The division of units is merely a logical functional division; in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or communication connections shown or discussed may be indirect coupling or communication connections through interfaces, devices, or units, and may be electrical, mechanical, or other forms.

[0242] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0243] In addition, the functional units in the various embodiments of this application 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.

[0244] If a function is implemented as a software functional unit 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 this application, in essence, or the part that contributes to the prior art, or a portion 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 of the various embodiments of this application. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, ROM, RAM, magnetic disks, or optical disks.

[0245] Those skilled in the art will understand that all or part of the steps of the above-described method embodiments can be implemented by hardware related to program instructions. The aforementioned program can be stored in a computer-readable storage medium. When executed, the program performs the steps of the above-described method embodiments; and the aforementioned storage medium includes various media capable of storing program code, such as ROM, RAM, magnetic disks, or optical disks.

[0246] Finally, it should be noted that other embodiments of this application will readily conceive of by those skilled in the art upon consideration of the specification and practice of the invention disclosed herein. This application is intended to cover any variations, uses, or adaptations of this application that follow the general principles of this application and include common knowledge or customary techniques in the art not disclosed herein, and is not limited to the precise structures described above and shown in the accompanying drawings, and various modifications and changes may be made without departing from its scope.

Claims

1. A method for handling faults in a power distribution network, characterized in that, include: Based on the fault event sequence, switch change information, user power outage and restoration information, and network topology of the distribution network, the fault area of ​​the distribution network is determined; Based on the fault area and the network topology, the candidate transfer path is determined; The target power transfer path is determined from all candidate power transfer paths based on the load rate, historical failure count, number and type of users whose power can be restored for each candidate power transfer path.

2. The method according to claim 1, characterized in that, The process of determining the target power transfer path from all candidate power transfer paths based on the load rate, historical failure count, number and type of users with recoverable power for each candidate power transfer path includes: For each candidate power transfer path, the sub-scores corresponding to the load rate, the number of historical faults, the number of users with recoverable power supply, and the type are determined respectively; Calculate the total score of the candidate transfer path by weighted summation of all sub-scores; The candidate supply path with the highest total score is determined as the target supply path; The load rate and the number of historical faults are negatively correlated with the corresponding sub-scores, while the number of users with recoverable power supply is positively correlated with the corresponding sub-scores. The sub-scores corresponding to the types of users with recoverable power supply, namely hospital users, school users, government users, and industrial and commercial users, are greater than the sub-scores corresponding to the types of users with recoverable power supply, namely residential users.

3. The method according to claim 2, characterized in that, The step of determining the candidate transfer path with the highest total score as the target transfer path includes: The candidate supply path with the highest total score is determined as the intermediate supply path; Power flow calculation simulation is performed on the intermediate transfer path to verify the security of the intermediate transfer path and obtain the first verification result; If the first verification result indicates that the verification is successful, then the intermediate transfer path is determined as the target transfer path.

4. The method according to claim 1, characterized in that, The step of determining the fault area of ​​the distribution network based on the fault event sequence, switch change information, user power outage and restoration information, and network topology includes: The fault event sequence and the switch position information are obtained from the main and distribution integrated system. Obtain the user's power outage and restoration information from the metering automation system; Based on the user power outage and restoration information, cross-validation is performed on the distribution network faults indicated by the fault event sequence and the switch change information to generate a second verification result; If the second verification result indicates that the verification is successful, then the fault area of ​​the distribution network is determined based on at least one of the user power outage and restoration information, the fault event sequence, and the switch change information, as well as the network topology.

5. The method according to claim 1, characterized in that, The step of determining the candidate supply transfer path based on the fault area and the network topology includes: On the non-faulty power supply side, identify the interconnecting switch in the network topology that is electrically adjacent to the faulty area; For each of the aforementioned interconnecting switches, the path for supplying power to the faulty area by closing the interconnecting switch, starting from the non-faulty power supply side connected to the interconnecting switch, is determined as the candidate transfer path.

6. The method according to any one of claims 1-5, characterized in that, The method further includes: Based on the fault area, generate fault inspection information; Based on the fault inspection information, an inspection task instruction is generated, which includes the coordinates of the fault area; The patrol task instruction is sent to the UAV inspection system so that the UAV inspection system can inspect the faulty area.

7. A power distribution network fault handling device, characterized in that, include: The first determining module is used to determine the fault area of ​​the distribution network based on the fault event sequence, switch change information, user power outage and restoration information, and network topology. The second determining module is used to determine the candidate transfer path based on the fault area and the network topology; The third determination module is used to determine the target power transfer path from all candidate power transfer paths based on the load rate, historical failure count, number and type of users whose power can be restored for each candidate power transfer path.

8. An electronic device, characterized in that, include: Memory and processor; The memory stores computer-executed instructions; The processor executes computer execution instructions stored in the memory, causing the processor to perform the method as described in any one of claims 1-6.

9. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer-executable instructions, which, when executed by a processor, are used to implement the method as described in any one of claims 1-6.

10. A computer program product, characterized in that, Includes a computer program that, when executed by a processor, implements the method described in any one of claims 1-6.

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