Low-voltage power distribution network fault positioning method based on electric meter cooperative communication

Abstract

The invention provides a low-voltage power distribution network fault positioning method based on electric meter cooperative communication, and the method comprises the steps: enabling each intelligent electric meter to monitor the electrical parameters of a node where the intelligent electric meter is located in real time, generating initial fault information when any target intelligent electric meter in a plurality of intelligent electric meters determines that a fault exists according to the electrical parameters, the target intelligent electric meter sends the initial fault information to the adjacent intelligent electric meter according to the communication topology so as to send the initial fault information to the main processor through the communication topology, and the main processor analyzes and determines the fault position and the fault type of the low-voltage power distribution network according to the initial fault information and the communication topology. According to the invention, each intelligent meter generates the initial fault information according to the monitored electrical parameters in real time and based on the electrical parameters, and sends the initial fault information to the main processor through the communication topology, so that the fault detection efficiency is improved, the process is simple, and extra manpower and material resource investment is not needed.

Description

Technical Field

[0001] This application relates to the field of fault location technology, and more specifically, to a fault location method for low-voltage distribution networks based on meter collaborative communication. Background Technology

[0002] Low-voltage distribution networks are the final link in the power system, directly serving a large number of electricity users. Their operational reliability directly affects user experience and economic benefits. However, low-voltage distribution networks have long lines, many branches, and complex environments, making them susceptible to external damage, equipment aging, severe weather, and other factors that can lead to faults such as short circuits and line breaks.

[0003] In existing technologies, faults in low-voltage distribution networks are generally detected by manual inspection or by installing fault detection devices at key nodes.

[0004] However, existing fault detection methods are inefficient, and the use of fault detection devices requires additional installation, which is not only cumbersome but also brings significant additional investment. Summary of the Invention

[0005] The purpose of this application is to provide a low-voltage distribution network fault location method based on meter collaborative communication, in order to address the shortcomings of the prior art and solve the problems of low detection efficiency and cumbersome process in the prior art.

[0006] To achieve the above objectives, the technical solution adopted in this application is as follows: In a first aspect, this application provides a fault location method for low-voltage distribution networks based on smart meter collaborative communication, applied to a smart meter collaborative communication system. The system includes: multiple smart meters and a main processor, wherein each of the smart meters is communicatively connected to the main processor, and a communication topology is formed among the multiple smart meters. The method includes: Each of the aforementioned smart meters monitors the electrical parameters of its respective node in real time; When any target smart meter among the multiple smart meters determines that a fault exists based on the electrical parameters, initial fault information is generated; The target smart meter sends the initial fault information to adjacent smart meters according to the communication topology, so as to send the initial fault information to the main processor through the communication topology; The main processor determines the fault location and fault type of the low-voltage distribution network based on the initial fault information and the communication topology analysis.

[0007] Optionally, the target smart meter sends the initial fault information to adjacent smart meters according to the communication topology, so as to send the initial fault information to the main processor through the communication topology, including: The target smart meter sends the initial fault information to adjacent smart meters according to the communication topology. The initial fault information includes: the fault electrical parameters determined by the target smart meter and the corresponding fault timestamp. After receiving the initial fault information, the adjacent smart meter reads its own electrical parameters corresponding to the fault timestamp carried by the initial fault information. The adjacent smart meters generate new fault information based on their own electrical parameters and the initial fault information, and send the new fault information to the adjacent smart meters according to the communication topology, and so on. After being processed by the smart meters on the topology path, the final fault information is sent to the main processor.

[0008] Optionally, when any target smart meter among the plurality of smart meters determines that a fault exists based on the electrical parameters, initial fault information is generated, including: When any target smart meter among the plurality of smart meters detects a fault triggering condition based on the electrical parameters, initial fault information is generated. The fault triggering condition includes at least one of the following: voltage instantaneously drops below a preset voltage threshold, voltage completely disappears, or current instantaneously increases above a preset current threshold.

[0009] Optionally, the main processor determines the fault location and fault type of the low-voltage distribution network based on the initial fault information and the communication topology analysis, including: The main processor determines, based on the initial fault information and the communication topology, the first fault meter with overvoltage or undervoltage in the last reported fault information and the second fault meter with completely lost voltage in the first reported fault information. The main processor determines the fault location on the fault path between the first fault meter and the second fault meter according to the communication topology. The main processor determines the fault type based on the electrical parameters corresponding to the upstream and downstream meters of the fault path.

[0010] Optionally, the main processor determines the fault type based on the electrical parameters corresponding to the upstream and downstream meters of the fault path, including: If the main processor determines that the upstream meter has an overcurrent based on the electrical parameters of the upstream meter in the fault path, and determines that the downstream meter has a voltage loss based on the electrical parameters of the downstream meter, then the fault type is determined to be a short-circuit fault.

[0011] Optionally, the main processor determines the fault type based on the electrical parameters corresponding to the upstream and downstream meters of the fault path, including: If the main processor determines that the current fluctuation of the upstream meter is within a preset range based on the electrical parameters of the upstream meter in the fault path, and determines that the downstream meter is undervoltage based on the electrical parameters of the downstream meter, then the fault type is determined to be an open-circuit fault.

[0012] Optionally, the main processor determines the fault type based on the electrical parameters corresponding to the upstream and downstream meters of the fault path, including: The electrical parameters of the upstream meter and the downstream meter of the fault path are input into a pre-trained fault prediction model, and the fault prediction model outputs the fault type.

[0013] Optionally, the method further includes: The main processor generates a fault report based on the fault location and the fault type; The main processor sends the fault report to the management platform of the area where the fault is located.

[0014] Optionally, the multiple smart meters may communicate with each other using one or more of the following methods: power line carrier communication, low-power wireless communication, NB-IoT, or 4G / 5G cellular communication.

[0015] Secondly, this application provides a smart meter collaborative communication system, which includes: multiple smart meters and a main processor, wherein the multiple smart meters are all communicatively connected to the main processor and a communication topology is formed among the multiple smart meters, and the main processor is used to execute the low-voltage distribution network fault location method based on smart meter collaborative communication as described in the first aspect.

[0016] The beneficial effects of this application are as follows: Each smart meter monitors the electrical parameters of its node in real time. When any target smart meter among multiple smart meters determines a fault based on the electrical parameters, initial fault information is generated. The target smart meter sends the initial fault information to adjacent smart meters according to the communication topology, thereby transmitting the initial fault information to the main processor. The main processor analyzes the initial fault information and the communication topology to determine the fault location and fault type of the low-voltage distribution network. This embodiment improves fault location efficiency, achieves full circuit coverage, reduces manpower and material costs, directly improves the operation and maintenance efficiency of the distribution network, shortens power outage time, and improves the user's electricity experience through real-time monitoring of each smart meter and collaborative verification by adjacent smart meters. Attached Figure Description

[0017] To more clearly illustrate the technical solutions of the embodiments of this application, the accompanying drawings used in the embodiments will be briefly introduced below. It should be understood that the following drawings only show some embodiments of this application and should not be regarded as a limitation of the scope. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.

[0018] Figure 1 This is a schematic diagram of the structure of a smart meter collaborative communication system provided in an embodiment of this application; Figure 2 This is a flowchart illustrating a low-voltage distribution network fault location method based on meter collaborative communication provided in an embodiment of this application. Figure 3 This is a flowchart illustrating an initial fault information transmission process provided in an embodiment of this application; Figure 4 This is a flowchart illustrating a method for determining the location and type of a fault in a low-voltage distribution network, as provided in an embodiment of this application. Detailed Implementation

[0019] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. It should be understood that the accompanying drawings in this application are for illustrative and descriptive purposes only and are not intended to limit the scope of protection of this application. Furthermore, it should be understood that the schematic drawings are not drawn to scale. The flowcharts used in this application illustrate operations implemented according to some embodiments of this application. It should be understood that the operations in the flowcharts may not be implemented in sequence, and steps without logical contextual relationships may be reversed or implemented simultaneously. In addition, those skilled in the art, guided by the content of this application, may add one or more other operations to the flowcharts, or remove one or more operations from the flowcharts.

[0020] Furthermore, the described embodiments are merely some, not all, of the embodiments of this application. The components of the embodiments of this application described and illustrated herein can typically 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 the 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.

[0021] It should be noted that the term "comprising" will be used in the embodiments of this application to indicate the presence of the features declared thereafter, but does not exclude the addition of other features.

[0022] In existing technologies, manual inspections or the installation of fault detection devices at key nodes are typically used to detect faults in low-voltage distribution networks. However, this detection method is inefficient, and the use of fault detection devices requires additional installation, which is not only cumbersome but also incurs significant additional investment.

[0023] Based on this, this application proposes a fault location method for low-voltage distribution networks based on smart meter collaborative communication. In this method, each smart meter monitors the electrical parameters of its node in real time. Once a smart meter determines that a fault exists based on the electrical parameters, it generates initial fault information and sends it to adjacent smart meters according to the communication topology. This initial fault information is then transmitted to the main processor via the communication topology. The main processor analyzes the initial fault information and the communication topology to determine the fault location and fault type in the low-voltage distribution network. This application improves fault detection efficiency by having each smart meter generate initial fault information based on monitored electrical parameters in real time and then transmit the initial fault information to the main processor via the communication topology. The process is simple and requires no additional manpower or material resources.

[0024] Figure 1 This is a schematic diagram of the structure of a smart meter collaborative communication system provided in an embodiment of this application. Figure 1 As shown, the smart meter collaborative communication system can be applied in power distribution networks, such as low-voltage distribution networks. Taking a low-voltage distribution network as an example, it includes a distribution transformer T, a main line L0, and multiple branch lines L1, L2, L3, etc. Multiple electricity users can be distributed along these branch lines, and smart meters M1, M2, M3, etc., are installed on the lines connecting each user to the branch. Each smart meter connects to the main processor via power line communication (PLC) or a wireless communication network. Each smart meter has both point-to-point and broadcast communication capabilities to form a communication topology. The main processor can be a data concentrator unit (DCU) or a master station system. When the main processor is the master station system, each smart meter first connects to the DCU, and the DCU then communicates with the master station system via the public network.

[0025] Optionally, each smart meter not only has traditional electricity metering functions, but also integrates data acquisition, status sensing and communication interaction modules, and can act as a distributed monitoring node to capture the power grid status at its location in real time.

[0026] Optionally, the communication topology refers to the connection relationships and data transmission paths between smart meters within a region. The communication topology is pre-stored locally on each smart meter and in the main processor to define adjacent nodes for data transmission.

[0027] Next, refer to Figure 2This paper introduces the steps and flow of a low-voltage distribution network fault location method based on meter collaborative communication. Figure 2 This is a flowchart illustrating a low-voltage distribution network fault location method based on meter collaborative communication provided in an embodiment of this application.

[0028] S201. Each smart meter monitors the electrical parameters of its node in real time.

[0029] Among them, electrical parameters are key electrical signal indicators that reflect the operating status of the power grid, mainly including voltage, current, phase angle, power, etc., which serve as the core basis for judging faults.

[0030] As an optional implementation, smart meters use built-in hardware modules such as voltage sensors and current transformers to collect electrical parameters of the node in real time. The collection frequency is typically on the order of milliseconds to ensure that instantaneous changes can be captured when a fault occurs. Specifically, the raw data collected by the smart meter is preprocessed by the microprocessor built into the meter, including filtering and calibration, and then stored in a local cache with timestamps. The processed data is then reported to the main controller at a frequency lower than the collection frequency.

[0031] S202. When any target smart meter among multiple smart meters determines that there is a fault based on electrical parameters, initial fault information is generated.

[0032] Optionally, faults may include short circuits, open circuits, undervoltage, overcurrent, etc., which can cause electrical parameters to deviate from the normal range. Among them, a short circuit is manifested as a sudden increase in current, an open circuit is manifested as a sudden drop in voltage to 0, undervoltage is manifested as a voltage below the normal threshold, and overcurrent is manifested as a current exceeding the safe range.

[0033] Optionally, the initial fault information can be basic fault data generated by the first smart meter to detect a fault. The initial fault information may include: the identifier of the target smart meter, the electrical parameters at the time of the fault, the fault timestamp, and the preliminary fault characteristics. The electrical parameters at the time of the fault may include the voltage value during voltage loss or the current value during overcurrent. It is worth noting that the preliminary fault characteristics in the initial fault information can be the parameter performance determined in real time by the target smart meter based on preset thresholds and electrical parameters, such as voltage loss or overcurrent. For example, if smart meters M3 and M4 are triggered first, the initial fault information for smart meter M3 can be {ID:M3,Event:OverCurrent, V:80V, I:500A, Timestamp:t0}, and the initial fault information for smart meter M4 can be {ID:M4,Event:VoltageLoss, V:0V, I:0A, Timestamp:t0}.

[0034] As an optional implementation, the target smart meter uses a preset fault detection algorithm to compare real-time collected electrical parameters with corresponding preset thresholds. For example, if the electrical parameters exceed the threshold and the duration exceeds a preset time threshold, a fault is determined to have occurred. At this time, the target smart meter immediately triggers a fault mode, that is, it extracts the electrical parameters at the time of the fault from the local cache, combines them with its own identity identifier and timestamp, and packages them to generate initial fault information, providing basic data for subsequent collaborative communication.

[0035] S203. The target smart meter sends initial fault information to adjacent smart meters according to the communication topology, so as to send the initial fault information to the main processor through the communication topology.

[0036] Optionally, each smart meter can pre-store the identifiers and Internet Protocol Addresses (IP addresses) of its neighboring smart meters in its local memory according to the communication topology. When information needs to be sent, the information is sent directly according to the identifiers of the neighboring smart meters stored in the local memory.

[0037] As an optional implementation, the target smart meter sends initial fault information to adjacent smart meters. The adjacent smart meters determine their own electrical parameters based on the fault timestamp in the initial fault information and send their own electrical parameters along with the initial fault information as new fault information to the main processor. The new fault information includes the initial fault information of the target smart meter and the electrical parameters of the adjacent smart meters.

[0038] As an alternative implementation, after the target smart meter generates initial fault information, it sends the initial fault information to adjacent smart meters. Each adjacent smart meter determines its own electrical parameters based on the fault timestamp, then uses its own electrical parameters and the initial fault information as new fault information, and sends this new fault information to the smart meters adjacent to it. This process continues until all smart meters in the topology path containing the target smart meter have generated their own electrical parameters and new fault information, and then send the final fault information to the main processor. Optionally, the final fault information includes the initial fault information and the electrical parameters of all smart meters in the topology path.

[0039] As another optional implementation, after the target smart meter generates initial fault information, it directly reports the initial fault information to the main processor and simultaneously sends the initial fault information to adjacent smart meters. The adjacent smart meters determine their own electrical parameters at the fault timestamp based on the fault timestamp in the initial fault information, and use their own electrical parameters and the fault timestamp as new fault information. They then report the new fault information to the main processor and send it to the adjacent smart meters. This process continues until all smart meters on the topology path where the faulty meter is located report fault information to the main processor, so that the main processor can align the reported fault information with the fault timestamp of the initial fault information.

[0040] The topology path, in this context, describes the path formed by smart meters with strongly correlated electrical parameters throughout the low-voltage distribution network communication topology. The communication topology is the connection structure formed by meters according to physical routes, such as main lines or branch lines, and the connection structure can be a tree structure or a chain structure. For example, if smart meters M1, M2, and M3 are sequentially adjacent in branch L1, then smart meters M1, M2, and M3 are located in the same topology path.

[0041] S204. The main processor determines the fault location and fault type of the low-voltage distribution network based on the initial fault information and communication topology analysis.

[0042] Optionally, the main processor analyzes the initial fault information, communication topology, and the electrical parameters of the smart meters along the topology path to determine the fault location and fault type in the low-voltage distribution network.

[0043] The fault location refers to the specific line section in the distribution network where the fault occurred. It can be located to the line between two adjacent smart meters, such as the L1 branch line between smart meter M2 and smart meter M3.

[0044] As an optional implementation, after receiving the final fault information, the main processor determines the fault location by combining the communication topology as follows: It compares the initial fault information of the target smart meter with the electrical parameters of the smart meters on the topology path where the target smart meter is located, identifies the location of the state change, and uses this state change location as the fault location. The state change location can be a pair of adjacent nodes from the faulty smart meter to the normal smart meter. For example, if smart meter M3 is in a voltage loss state, and the adjacent smart meter M2 is in a normal state, then the fault location is the line segment between smart meters M2 and M3.

[0045] The steps to determine the fault type are as follows: Based on the initial fault information of the target smart meter, the electrical parameters of the smart meters on the topology path where the target smart meter is located, and the preset voltage and current thresholds, the fault type is determined. In this embodiment, each smart meter monitors the electrical parameters of its node in real time. When any target smart meter among multiple smart meters determines a fault based on the electrical parameters, initial fault information is generated. The target smart meter sends the initial fault information to adjacent smart meters according to the communication topology, thereby transmitting the initial fault information to the main processor. The main processor analyzes the initial fault information and the communication topology to determine the fault location and type of the low-voltage distribution network. This embodiment, through real-time monitoring by each smart meter and collaborative verification by adjacent smart meters, improves fault location efficiency, achieves full circuit coverage, reduces manpower and material costs, directly improves the operation and maintenance efficiency of the distribution network, shortens power outage time, and improves the user's electricity experience.

[0046] Figure 3 This is a flowchart illustrating an initial fault information transmission process provided in an embodiment of this application. Next, refer to... Figure 3 The process of sending initial fault information from the target smart meter to adjacent smart meters according to the communication topology in step S203 above, and then sending the initial fault information to the main processor through the communication topology, will be described.

[0047] S301. The target smart meter sends initial fault information to adjacent smart meters according to the communication topology. The initial fault information includes: the fault electrical parameters determined by the target smart meter and the corresponding fault timestamp.

[0048] Optionally, the target smart meter can determine its upstream and downstream smart meters in the communication topology path based on the communication topology, and treat both upstream and downstream smart meters as adjacent smart meters. Specifically, the upstream smart meter is the one closest to the power source, and the downstream smart meter is the one furthest from the power source.

[0049] Specifically, the target smart meter can communicate using a PLC or a wireless self-organizing network. When a fault occurs, the target smart meter can switch from the normal operation mode to the fault communication mode, suspending non-emergency data transmission, such as regular electricity consumption data, and prioritizing the use of communication resources to send initial fault information to ensure timeliness.

[0050] Optionally, the initial fault information is packaged according to a preset protocol format, such as including a frame header, target smart meter identifier, fault parameters, timestamp, check code, etc. The check code is used by adjacent smart meters to verify data integrity in order to avoid errors during transmission. If the verification fails, a retransmission is requested.

[0051] Optionally, the target smart meter first sends a fault notification broadcast to all neighboring smart meters, triggering the neighboring smart meters to enter a collaborative listening state, and then sends complete initial fault information in a targeted manner to reduce invalid communication.

[0052] S302. After receiving the initial fault information, the adjacent smart meter reads its own electrical parameters corresponding to the fault timestamp carried in the initial fault information.

[0053] Among them, the self-electrical parameters refer to the voltage, current, phase, and other data collected by adjacent meters at the precise time of the fault timestamp. Optionally, each smart meter has a built-in time-series database that stores high-frequency collected data within the most recent preset time period in real time in key-value pairs of timestamp electrical parameters, ensuring that parameters at the time of the fault can be traced back.

[0054] Optionally, the time deviation of all smart meters in the distribution network can be controlled within a preset time using the clock signal in the PLC carrier or a network time protocol. After receiving the initial fault information, adjacent meters extract the fault timestamp and accurately locate the electrical parameters at that moment in their local cache.

[0055] Optionally, after receiving the initial fault information, the adjacent smart meter triggers a priority interrupt, that is, it suspends low-priority tasks, such as screen display updates, and prioritizes the execution of timestamp parsing and parameter reading to ensure that the processing is completed in a short time and avoid delays in information transmission.

[0056] S303. Adjacent smart meters generate new fault information based on their own electrical parameters and initial fault information, and send the new fault information to adjacent smart meters according to the communication topology. This process is repeated for each smart meter along the topology path, and then the final fault information is sent to the main processor.

[0057] Optionally, new fault information always retains the original fault information and sequentially adds the current smart meter's own electrical parameters to form a chain-like data structure.

[0058] Optionally, the process stops and the final fault information is sent to the main processor in the following three situations: First, when the fault information is transmitted to a smart meter directly connected to the main processor, that meter stops transmitting to other meters and sends the fault information directly to the main processor. Second, if the fault information is transmitted to a smart meter at the end of the distribution network, such as the downstream smart meter M3 on a branch line, and there are no downstream adjacent meters in its topology path, then that smart meter sends the fault information to the main processor. Third, a preset maximum number of hops is used. If the number of hops exceeds this maximum, the process automatically stops and the fault information is sent to the main processor to prevent the information from looping infinitely in the ring topology. The current hop count can be recorded in the fault information.

[0059] Optionally, if the electrical parameter information corresponding to the same meter or the initial fault information of the target smart meter is transmitted to the same meter through different paths, such as the intersection of a branch line and a main line, the meter can merge duplicate data by comparing the timestamp and the meter identifier to avoid the main processor receiving redundant information.

[0060] In this embodiment, the received fault information is processed sequentially by adjacent smart meters, and the final fault information is sent to the main processor. This enables fault information to be verified from a single point of detection to node collaborative verification, which ensures data integrity and improves communication efficiency.

[0061] As an optional implementation, the process of generating initial fault information in step S202 above when any target smart meter among the multiple smart meters determines that there is a fault based on electrical parameters is as follows: when any target smart meter among the multiple smart meters detects a fault triggering condition based on electrical parameters, initial fault information is generated, wherein the fault triggering condition includes at least one of the following: voltage instantaneously drops below a preset voltage threshold, voltage completely disappears, or current instantaneously increases above a preset current threshold.

[0062] The instantaneous voltage drop below the preset voltage threshold refers to a sudden decrease in the voltage value detected by the smart meter within a very short period of time, falling below the preset normal voltage threshold, but not completely dropping to zero. For example, if the voltage at the user end of a 220V single-phase user suddenly drops below 150V and lasts for more than 10ms, this condition is triggered. Causes of this condition could include short-circuit faults, sudden starts of heavy loads, or poor line contact.

[0063] Complete voltage loss refers to a sudden drop in voltage detected by the smart meter to 0V and persisting for a certain period of time. Common causes of complete voltage loss include: broken wiring, tripped distribution transformer, and disconnected main switch.

[0064] A sudden increase in current exceeding the preset current threshold refers to a rapid increase in the current value detected by the smart meter, exceeding the preset safe current threshold within a very short period of time. Common causes of this sudden increase include: short-circuit faults, user-side equipment malfunctions, and line overloads.

[0065] Optionally, during operation, each smart meter may determine in real time whether electrical parameters meet the fault triggering conditions. If so, it may generate initial fault information. Multiple smart meters may detect the fault triggering conditions simultaneously and generate initial fault information at the same time.

[0066] In this embodiment, the target smart meter detects fault triggering conditions based on electrical parameters and generates initial fault information, thereby ensuring that faults can be captured quickly and interference can be effectively filtered, laying the foundation for subsequent collaborative verification and main processor analysis.

[0067] Next, refer to Figure 4 The process by which the main processor determines the fault location and type of the low-voltage distribution network based on initial fault information and communication topology analysis in step S204 above is described. Figure 4 This is a flowchart illustrating a method for determining the location and type of a fault in a low-voltage distribution network, as provided in an embodiment of this application.

[0068] S401. Based on the initial fault information and communication topology, the main processor determines the first fault meter with overvoltage or undervoltage in the last reported fault information and the second fault meter with completely lost voltage in the first reported fault information.

[0069] Optionally, in low-voltage distribution network faults, there is a clear spatial correlation between overvoltage or undervoltage and complete voltage loss. That is, upstream of the fault point, there may only be abnormal overvoltage or undervoltage, while downstream, the fault will cause a complete voltage loss. By identifying these first and second faulty meters, the scope of the fault can be quickly located. For example, if a line breaks at a certain point, the upstream meter may experience undervoltage due to changes in line impedance, while the downstream meter will experience complete voltage loss; the section between these two is the location of the fault.

[0070] As an optional implementation, after receiving the final fault information, the main processor first organizes the data according to the smart meter's identifier, timestamp, and electrical parameters, and then filters out all faulty meters that report overvoltage, undervoltage, or complete voltage loss, while excluding meters that are in normal condition.

[0071] Specifically, along the communication topology path from the power supply end to the user end, the voltage status of each faulty meter will be checked sequentially to find the dividing point between overvoltage / undervoltage and complete voltage loss. The last overvoltage / undervoltage meter upstream of this dividing point will be designated as the first faulty meter. Downstream of the first faulty meter, the first smart meter to report complete voltage loss will be identified as the second faulty meter.

[0072] For example, a topology path includes, in sequence: transformer T, smart meter M1, smart meter M2, smart meter M3 and smart meter M4. If smart meter M1 and smart meter M2 experience undervoltage, and smart meter M3 and smart meter M4 experience voltage loss, then smart meter M2 is designated as the first faulty meter, and smart meter M3 is designated as the second faulty meter.

[0073] Optionally, if no matching meter is found, for example, if all faulty meters are undervoltage, the fault can be determined to be between the distribution transformer and the first undervoltage meter, taking into account the status of the distribution transformer, to avoid missing any faults.

[0074] S402. The main processor determines the fault location on the fault path between the first fault meter and the second fault meter according to the communication topology.

[0075] Optionally, the main processor extracts the physical line path between the first faulty meter and the second faulty meter based on the communication topology. This path is the core scope of the fault investigation.

[0076] Specifically, by using the pre-stored communication topology, it is confirmed whether the first faulty meter and the second faulty meter are directly adjacent nodes. If so, the fault location is directly determined to be the line segment between the first faulty meter and the second faulty meter. If not, the status of the smart meter between the first faulty meter and the second faulty meter is further analyzed, such as whether it was not reported due to a communication failure, thereby narrowing down the fault node to the nearest abnormal and normal node.

[0077] Optionally, the information about the determined fault location may include: line name, starting point, ending point, and distance estimate, where the distance estimate is the distance between the starting point and the ending point.

[0078] Optionally, the fault location can be visualized via text or a map, and an alarm message can be generated. For example, the system automatically generates an alarm message stating: "A fault has occurred on line XX in area XX, with the estimated location between smart meter M3 (address: XX Road, XX No.) and smart meter M4 (address: XX Road, XX No.)", and dispatches a work order to the maintenance personnel.

[0079] S403: The main processor determines the fault type based on the electrical parameters corresponding to the upstream and downstream meters in the fault path.

[0080] Optionally, the upstream meter is the first faulty meter and all smart meters upstream of the first faulty meter, and the downstream meter is all smart meters downstream of the second faulty meter.

[0081] Specifically, the main processor can determine the fault type based on the voltage and current parameters of the upstream and downstream meters along the fault path.

[0082] In this embodiment, the first fault meter and the second fault meter are determined based on the initial fault information and the communication topology. Then, the fault location between the first fault meter and the second fault meter is determined based on the communication topology. The fault type is determined based on the electrical parameters corresponding to the upstream and downstream meters, thereby forming a fault diagnosis closed loop and providing accurate decision-making basis for the efficient operation and maintenance of low-voltage distribution networks.

[0083] As an optional implementation, in step S403 above, the main processor determines the fault type based on the electrical parameters corresponding to the upstream and downstream meters of the fault path using three methods.

[0084] Specifically, the first method is as follows: if the main processor determines the overcurrent of the upstream meter based on the electrical parameters of the upstream meter in the fault path, and determines the undervoltage of the downstream meter based on the electrical parameters of the downstream meter, then the fault type is determined to be a short-circuit fault.

[0085] Optionally, a short-circuit fault manifests as a low-impedance abnormal loop in the line, such as direct contact between phase lines or between a phase line and the neutral line, leading to a sharp increase in current. Simultaneously, the downstream of the short-circuit point experiences a complete power outage due to the current being diverted by the abnormal loop. Upstream meters, being close to the power source, must bear the enormous current generated by the short circuit, while downstream meters, due to the current being cut off at the short-circuit point, experience no current flow and lose voltage, resulting in the characteristics of upstream overcurrent and downstream voltage loss.

[0086] In this embodiment, the fault type is determined to be a short-circuit fault by judging whether the upstream meter is overcurrent and whether the downstream meter is undervoltage, which is efficient and accurate.

[0087] The second method is as follows: if the main processor determines that the current fluctuation of the upstream meter is within a preset range based on the electrical parameters of the upstream meter in the fault path, and determines that the downstream meter is undervoltage based on the electrical parameters of the downstream meter, then the fault type is determined to be a line break fault.

[0088] Optionally, a line breakage fault manifests as a physical break in the line, such as a phase wire or neutral wire breakage. The line breakage causes the downstream of the fault point to be completely disconnected from the power supply, forming an open circuit. Therefore, the downstream loses voltage due to the lack of a current path. Since no abnormal loop is formed upstream, the current remains within the normal range, and may only decrease slightly due to the disconnection of the downstream user, but there is no overcurrent. This results in the characteristic of normal upstream current but voltage loss downstream.

[0089] Optionally, after a downstream meter reports a voltage loss, the main processor immediately sends a low-voltage wake-up command to it. If the downstream meter can respond to the command normally, it proves that its own power supply is not interrupted and only the grid side is experiencing a voltage loss, thus ruling out a fault in the meter itself. If it cannot respond, it indicates that the smart meter is faulty, and a fault alarm signal needs to be issued according to the identifier of the smart meter. The fault alarm signal includes the identifier of the faulty smart meter.

[0090] In this embodiment, the fault type is determined to be a line break fault based on whether the current fluctuation of the upstream meter is within a preset range and whether the downstream meter loses voltage, which is efficient and accurate.

[0091] The third method involves inputting the electrical parameters of both the upstream and downstream meters along the fault path into a pre-trained fault prediction model, which then outputs the fault type.

[0092] The training process of the large-scale fault prediction model includes: transforming the electrical parameters of smart meters upstream and downstream of the fault path in the sample data into features that the model can understand; that is, converting voltage and current waveform segments within a preset time period before and after the fault into time-series features; converting peak values, rates of change, and fluctuation amplitudes of voltage and current into abrupt change features; and converting the time difference, current ratio, and voltage ratio of upstream and downstream meter parameters into correlation features. A time-series classification model is used, trained with sample data, and the large-scale fault prediction model is obtained through iterative correction of the model.

[0093] After a fault occurs, the main processor extracts the real-time electrical parameters of the upstream and downstream meters at the time of the fault and before and after it, organizes them into input vectors according to the training format, and feeds the input vectors into the pre-trained fault prediction model. The model calculates through a multi-layer network and outputs the probability of each fault type. The type with the highest probability is taken as the final fault type. At the same time, it outputs key influencing features. For example, when the model judges a short circuit, it will mark "the upstream current change rate of 15A / ms is the main basis", thereby improving interpretability.

[0094] In this embodiment, the fault type is predicted by a large fault prediction model, which is suitable for systems with many branches in the distribution network and complex fault scenarios. It can improve the accuracy and robustness of fault type judgment while maintaining real-time performance.

[0095] As an optional implementation method, the low-voltage distribution network fault location method based on meter collaborative communication also includes the following methods: Optionally, the main processor generates a fault report based on the fault location and fault type.

[0096] The fault report may include: basic information, fault location, fault type, key parameter basis, affected area, and handling suggestions. Basic information may include the fault occurrence time, transformer substation name, and line number. Key parameter basis may be the electrical parameters of the target faulty meter and a preliminary assessment. Affected area includes the target faulty meter and the user area covered by the meter with abnormal electrical parameters. Handling suggestions may be generated based on the fault location and fault type.

[0097] For example, if a short circuit fault occurs between smart meters M2 and M3 on branch L1, a fault report will be generated: [Emergency Fault Report]; Time: 2025-09-26 14:30:12; Substation: XX Community, Substation No. 1; Fault Location: Section between L1 branch line M2 (installation location: Unit 1, Building 3) and M3 (Unit 2, Building 4) (approximately 25 meters from M2); Fault Type: Phase-to-phase short circuit fault; Parameter Basis: M2 current 62A (rated 20A), voltage 78V; M3 voltage 0V, current 0A; Affected Users: 3 households (M3 associated users); Recommendation: Immediately arrange for a repair team to bring insulated tools, first disconnect the L1 branch switch, check the short circuit point and replace the wires.

[0098] Optionally, the main processor sends a fault report to the management platform in the region where the fault is located.

[0099] Optionally, the management platform can be a local maintenance terminal, a power supply bureau dispatch center platform, or a user notification platform, etc. The local maintenance terminal can be used by on-site emergency repair personnel.

[0100] In this embodiment, the main processor generates a fault report based on the fault location and fault type, and sends the fault report to the management platform in the area where the fault location is located, thereby significantly shortening the fault response time and improving power supply reliability.

[0101] Optionally, multiple smart meters may communicate with each other using one or more of the following methods: power line carrier communication, low-power wireless communication, NB-IoT, or 4G / 5G cellular communication.

[0102] Power line carrier communication is a communication method that uses the low-voltage power lines where smart meters are located as the transmission medium and achieves data interaction by loading high-frequency signals. This method does not require laying additional communication lines, directly reuses the existing power network, has extremely low deployment costs, and its coverage is consistent with the power lines, naturally matching the distribution network topology, making it suitable for short-distance communication.

[0103] Low-power wireless communication uses low-power radio frequency signals to achieve wireless data transmission, supporting point-to-point or self-organizing networks. This method offers flexible deployment, is unaffected by power line interference, and boasts high reliability and low power consumption.

[0104] Narrowband Internet of Things (NB-IoT) is a narrowband IoT technology based on operator cellular networks. It has a very wide coverage, is suitable for distributed electricity meters in rural and suburban areas, and has low power consumption.

[0105] Fourth-generation mobile communication technology (4G / 5G) cellular communication utilizes operators' 4G / 5G networks to achieve high-speed, low-latency data transmission. This method offers low latency and wide coverage.

[0106] Alternatively, the above methods can be combined, such as using PLC within the distribution area and NB-IoT or 4G / 5G cellular communication for long distances, thereby balancing cost, reliability, and practicality.

[0107] In this embodiment, multiple smart meters communicate with each other using power line carrier communication, low-power wireless communication, NB-IoT, or 4G / 5G cellular communication, thereby improving reliability and reducing energy consumption.

[0108] This application also provides a smart meter collaborative communication system, which includes: multiple smart meters and a main processor. The multiple smart meters are all communicatively connected to the main processor, and a communication topology is formed among the multiple smart meters. The main processor is used to execute a low-voltage distribution network fault location method based on smart meter collaborative communication.

[0109] The above are merely specific embodiments of this application, but the scope of protection of this application is not limited thereto. Any changes or substitutions that can be easily conceived by those skilled in the art within the scope of the technology disclosed in this application should be included within the scope of protection of this application.

Claims

1. A method for fault location in low-voltage distribution networks based on meter collaborative communication, characterized in that, A collaborative communication system for smart meters is provided, the system comprising: multiple smart meters and a main processor, wherein each of the multiple smart meters is communicatively connected to the main processor, and a communication topology is formed among the multiple smart meters; the method includes: Each of the aforementioned smart meters monitors the electrical parameters of its respective node in real time; When any target smart meter among the multiple smart meters determines that a fault exists based on the electrical parameters, initial fault information is generated; The target smart meter sends the initial fault information to adjacent smart meters according to the communication topology, so as to send the initial fault information to the main processor through the communication topology; The main processor determines the fault location and fault type of the low-voltage distribution network based on the initial fault information and the communication topology analysis.

2. The low-voltage distribution network fault location method based on meter collaborative communication according to claim 1, characterized in that, The target smart meter sends the initial fault information to adjacent smart meters according to the communication topology, so as to send the initial fault information to the main processor through the communication topology, including: The target smart meter sends the initial fault information to adjacent smart meters according to the communication topology. The initial fault information includes: the fault electrical parameters determined by the target smart meter and the corresponding fault timestamp. After receiving the initial fault information, the adjacent smart meter reads its own electrical parameters corresponding to the fault timestamp carried by the initial fault information. The adjacent smart meters generate new fault information based on their own electrical parameters and the initial fault information, and send the new fault information to the adjacent smart meters according to the communication topology, and so on. After being processed by the smart meters on the topology path, the final fault information is sent to the main processor.

3. The low-voltage distribution network fault location method based on meter collaborative communication according to claim 2, characterized in that, When any target smart meter among the plurality of smart meters determines that a fault exists based on the electrical parameters, initial fault information is generated, including: When any target smart meter among the plurality of smart meters detects a fault triggering condition based on the electrical parameters, initial fault information is generated. The fault triggering condition includes at least one of the following: voltage instantaneously drops below a preset voltage threshold, voltage completely disappears, or current instantaneously increases above a preset current threshold.

4. The low-voltage distribution network fault location method based on meter collaborative communication according to claim 3, characterized in that, The main processor determines the fault location and fault type of the low-voltage distribution network based on the initial fault information and the communication topology analysis, including: The main processor determines, based on the initial fault information and the communication topology, the first fault meter with overvoltage or undervoltage in the last reported fault information and the second fault meter with completely lost voltage in the first reported fault information. The main processor determines the fault location on the fault path between the first fault meter and the second fault meter according to the communication topology. The main processor determines the fault type based on the electrical parameters corresponding to the upstream and downstream meters of the fault path.

5. The low-voltage distribution network fault location method based on meter collaborative communication according to claim 4, characterized in that, The main processor determines the fault type based on the electrical parameters corresponding to the upstream and downstream meters in the fault path, including: If the main processor determines that the upstream meter has an overcurrent based on the electrical parameters of the upstream meter in the fault path, and determines that the downstream meter has a voltage loss based on the electrical parameters of the downstream meter, then the fault type is determined to be a short-circuit fault.

6. The low-voltage distribution network fault location method based on meter collaborative communication according to claim 4, characterized in that, The main processor determines the fault type based on the electrical parameters corresponding to the upstream and downstream meters in the fault path, including: If the main processor determines that the current fluctuation of the upstream meter is within a preset range based on the electrical parameters of the upstream meter in the fault path, and determines that the downstream meter is undervoltage based on the electrical parameters of the downstream meter, then the fault type is determined to be an open-circuit fault.

7. The low-voltage distribution network fault location method based on meter collaborative communication according to claim 4, characterized in that, The main processor determines the fault type based on the electrical parameters corresponding to the upstream and downstream meters in the fault path, including: The electrical parameters of the upstream meter and the downstream meter of the fault path are input into a pre-trained fault prediction model, and the fault prediction model outputs the fault type.

8. The low-voltage distribution network fault location method based on meter collaborative communication according to claim 4, characterized in that, The method further includes: The main processor generates a fault report based on the fault location and the fault type; The main processor sends the fault report to the management platform of the area where the fault is located.

9. The low-voltage distribution network fault location method based on meter collaborative communication according to claim 1, characterized in that, The multiple smart meters communicate with each other using one or more of the following methods in combination: power line carrier communication, low-power wireless communication, NB-IoT, or 4G / 5G cellular communication.

10. A smart meter collaborative communication system, characterized in that, The smart meter collaborative communication system includes: multiple smart meters and a main processor, wherein the multiple smart meters are all communicatively connected to the main processor, and a communication topology is formed among the multiple smart meters, and the main processor is used to execute the low-voltage distribution network fault location method based on meter collaborative communication as described in any one of claims 1-9.

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