Low-voltage power distribution network topology file checking method and device, equipment and storage medium

Abstract

The application provides a low-voltage power distribution network topology file verification method and device, equipment and a storage medium, relating to the technical field of low-voltage power distribution. The method comprises: determining a target substation area to be verified in a low-voltage power distribution network, collecting power failure event logs generated by each household meter in the target substation area based on a preset multi-source power failure event, and then constructing a power failure time-space matrix based on the household meter identifier, power supply phase, planned power failure duration, actual power failure duration and power failure duration deviation recorded in each power failure event log. According to the power failure time-space matrix, each household meter in the target substation area is subjected to household correlation verification and / or household transformer relationship verification. The household correlation refers to the ownership relationship between the household meter and the power supply phase output by the distribution transformer in the low-voltage power distribution network, and the household transformer relationship refers to the ownership relationship between the household meter and the distribution transformer in the low-voltage power distribution network. The application can provide a complete topology file verification process for the low-voltage power distribution network.

Description

Technical Field

[0001] This application relates to the field of low-voltage power distribution technology, and in particular to a method, apparatus, equipment and storage medium for verifying the topology profile of a low-voltage power distribution network. Background Technology

[0002] Verification of the topology archives of low-voltage distribution networks is a crucial step in power system operation and management. Its core objective is to ensure the consistency between the power grid topology and the archive data, especially the consistency between the actual topology attribution of household meters and the topology attribution of household meters recorded in the topology archives.

[0003] Since household meters actively report power outage information after a power outage, the household meters that report outage information during the outage process are the actual outage meters. In existing technology, the actual outage meters are compared with the theoretical outage meters planned in advance for the outage process. If the actual outage meters and the theoretical outage meters are completely consistent, the low-voltage distribution network topology file is determined to be correct. If there are differences between the actual and theoretical outage meters, the information in the topology file for the actual outage meters that differ from the theoretical outage meters is determined to be incorrect.

[0004] However, existing technologies only determine whether the actual topology of the meter matches the topology recorded in the topology file, without further analyzing the actual topology of the meter in cases of inconsistency. Therefore, the topology file verification process for low-voltage distribution networks provided by existing technologies is incomplete. Summary of the Invention

[0005] This application provides a method, apparatus, device, and storage medium for verifying the topology profile of a low-voltage distribution network, in order to solve the technical problem that the topology profile verification process of a low-voltage distribution network is not complete in the prior art.

[0006] Firstly, this application provides a method for verifying the topology profile of a low-voltage distribution network, including:

[0007] Identify the target transformer substations awaiting verification in the low-voltage distribution network; collect outage event logs generated by each household meter in the target transformer substation based on preset multi-source power outage events;

[0008] Based on the meter identifier, power supply phase, planned outage duration, actual outage duration, and outage duration deviation recorded in each outage event log, a power outage spatiotemporal matrix is ​​constructed; wherein, the power supply phase represents the phase of the power source used to supply power to the meter as recorded in the topology file of the low-voltage distribution network, and the outage duration deviation represents the absolute value of the difference between the planned outage duration and the actual outage duration;

[0009] Based on the aforementioned power outage spatiotemporal matrix, the phase relationship verification and / or transformer relationship verification are performed on each meter in the target distribution area; wherein, the topology file verification includes phase relationship verification and transformer relationship verification, the phase relationship of the meter represents the affiliation relationship between the meter and the power output phase of the distribution transformer in the low-voltage distribution network, and the transformer relationship represents the affiliation relationship between the meter and the distribution transformer in the low-voltage distribution network.

[0010] In one possible design, based on the power outage spatiotemporal matrix, the meter relationships of each household in the target transformer area are verified, including:

[0011] Determine the planned power outage start time corresponding to the planned power outage duration in the power outage spatiotemporal matrix, and the actual power outage start time corresponding to the actual power outage duration; based on the planned power outage start time and the actual power outage start time, perform phase consistency analysis on the household meters, and determine the phase consistency analysis results;

[0012] Based on the phase consistency analysis results and the power outage duration deviation in the power outage time-space matrix, the phase relationship verification and / or transformer relationship verification are performed on each household meter in the target transformer area.

[0013] In one possible design, based on the planned power outage start time and the actual power outage start time, phase consistency analysis is performed on the customer meters, and the phase consistency analysis results are determined, including:

[0014] If the planned power outage start time is the same as the actual power outage start time, then the phase consistency analysis result of the household meter is determined to be phase consistent.

[0015] If the planned power outage start time and the actual power outage start time are inconsistent, then the phase consistency analysis result of the household meter is determined to be inconsistent.

[0016] In one possible design, based on the phase consistency analysis results and the outage duration deviation in the outage spatiotemporal matrix, the phase relationship verification and / or transformer relationship verification are performed on each meter in the target transformer area, including:

[0017] If the power outage duration deviation in the power outage time-space matrix is ​​less than or equal to a preset threshold, and the phase consistency analysis result indicates that the phases of the household meters are inconsistent, then the household meters are checked for phase relationship.

[0018] If the power outage duration deviation in the power outage spatiotemporal matrix is ​​less than or equal to a preset threshold, and the phase consistency analysis result indicates that the phases of the meters are consistent, then the topology file of the low-voltage distribution network is determined to be correct; wherein, the topology file indicates the topology affiliation of each meter.

[0019] If the power outage duration deviation in the power outage time-space matrix is ​​greater than the preset threshold, then the household meter will be checked for household-transformer relationship.

[0020] In one possible design, the method further includes:

[0021] Obtain the first verification result of the household relationship verification and / or the second verification result of the household change relationship verification;

[0022] Based on the actual topology attribution of the household meters indicated by the first verification result and / or the second verification result, the topology file of the low-voltage distribution network is corrected.

[0023] In one possible design, the preset multi-source power outage events include planned power outage events and fault power outage events.

[0024] In one possible design, the method further includes:

[0025] When the preset multi-source power outage event is the planned power outage event, the power outage start time indicated by the planned power outage event is determined as the planned power outage start time, and the power outage end time indicated by the planned power outage event is determined as the planned power outage end time.

[0026] When the preset multi-source power outage event is the fault power outage event, the fault point is determined; the power outage start time of the fault point is determined as the planned power outage start time, and the power outage end time of the fault point is determined as the planned power outage end time.

[0027] The absolute value of the difference between the planned power outage start time and the planned power outage end time is determined as the planned power outage duration; the actual power outage start time and the actual power outage end time are collected from the household meters, and the absolute value of the difference between the actual power outage start time and the actual power outage end time is determined as the actual power outage duration; the absolute value of the difference between the planned power outage duration and the actual power outage duration is determined as the power outage duration deviation.

[0028] Secondly, this application provides a topology verification device for a low-voltage distribution network, comprising:

[0029] The determination module is used to identify target transformer areas awaiting verification in the low-voltage distribution network.

[0030] The data acquisition module is used to collect power outage event logs generated by each household meter in the target transformer area based on preset multi-source power outage events;

[0031] The construction module is used to construct a power outage spatiotemporal matrix based on the meter identifier, power supply phase, planned power outage duration, actual power outage duration, and power outage duration deviation recorded in each power outage event log; wherein, the power supply phase represents the phase of the power source used to supply power to the meter as recorded in the topology file of the low-voltage distribution network, and the power outage duration deviation represents the absolute value of the difference between the planned power outage duration and the actual power outage duration;

[0032] The verification module is used to perform household phase relationship verification and / or household transformer relationship verification on each household meter in the target distribution area according to the power outage spatiotemporal matrix; wherein, the topology file verification includes household phase relationship verification and household transformer relationship verification, the household phase relationship represents the affiliation relationship between the household meter and the power output phase of the distribution transformer in the low-voltage distribution network, and the household transformer relationship represents the affiliation relationship between the household meter and the distribution transformer in the low-voltage distribution network.

[0033] In one possible design, the verification module includes:

[0034] The determination submodule is used to determine the planned power outage start time corresponding to the planned power outage duration in the power outage time-space matrix, and the actual power outage start time corresponding to the actual power outage duration.

[0035] The analysis submodule is used to perform phase consistency analysis on the household meters based on the planned power outage start time and the actual power outage start time, and to determine the phase consistency analysis results.

[0036] The verification submodule is used to perform household phase relationship verification and / or household transformer relationship verification on each household meter in the target transformer area based on the phase consistency analysis results and the power outage duration deviation in the power outage time-space matrix.

[0037] In one possible design, the analysis submodule includes: a first determining component, used for:

[0038] If the planned power outage start time is the same as the actual power outage start time, then the phase consistency analysis result of the household meter is determined to be phase consistent.

[0039] If the planned power outage start time and the actual power outage start time are inconsistent, then the phase consistency analysis result of the household meter is determined to be inconsistent.

[0040] In one possible design, the verification submodule includes:

[0041] The verification component is used to perform a household phase relationship verification on the household meter if the power outage duration deviation in the power outage time-space matrix is ​​less than or equal to a preset threshold and the phase consistency analysis result indicates that the phases of the household meter are inconsistent.

[0042] The second determining component is used to determine that the topology file of the low-voltage distribution network is correct if the power outage duration deviation in the power outage time-space matrix is ​​less than or equal to a preset threshold and the phase consistency analysis result indicates that the phases of the meters are consistent; wherein, the topology file indicates the topology affiliation of each meter.

[0043] The verification component is also used to perform household-to-transformer relationship verification on the household meter if the power outage duration deviation in the power outage time-space matrix is ​​greater than the preset threshold.

[0044] In one possible design, the verification submodule further includes:

[0045] A component is used to obtain the first verification result of the household relationship verification and / or the second verification result of the household change relationship verification.

[0046] A correction component is used to correct the topology profile of the low-voltage distribution network based on the actual topology affiliation of the household meters indicated by the first verification result and / or the second verification result.

[0047] In one possible design, the preset multi-source power outage events include planned power outage events and fault power outage events.

[0048] In one possible design, the determining module is further configured to:

[0049] When the preset multi-source power outage event is the planned power outage event, the power outage start time indicated by the planned power outage event is determined as the planned power outage start time, and the power outage end time indicated by the planned power outage event is determined as the planned power outage end time.

[0050] When the preset multi-source power outage event is the fault power outage event, the fault point is determined; the power outage start time of the fault point is determined as the planned power outage start time, and the power outage end time of the fault point is determined as the planned power outage end time.

[0051] The absolute value of the difference between the planned power outage start time and the planned power outage end time is determined as the planned power outage duration;

[0052] The data acquisition module is also used to collect the actual power outage start time and actual power outage end time of the household meter.

[0053] The determining module is further configured to determine the absolute value of the difference between the actual power outage start time and the actual power outage end time, which is the actual power outage duration; and to determine the absolute value of the difference between the planned power outage duration and the actual power outage duration, which is the power outage duration deviation.

[0054] Thirdly, this application provides an electronic device comprising: at least one processor and a memory; the memory storing computer-executable instructions; the at least one processor executing the computer-executable instructions stored in the memory, causing the at least one processor to perform the method described in the first aspect above and various possible designs.

[0055] Fourthly, embodiments of this application provide a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, implement the methods described in the first aspect above and various possible designs.

[0056] Fifthly, embodiments of this application provide a computer program product, including a computer program that, when executed by a processor, implements the methods described in the first aspect above and various possible designs.

[0057] This application provides a method, apparatus, equipment, and storage medium for verifying the topology files of a low-voltage distribution network. It identifies target transformer substations awaiting verification within the low-voltage distribution network and collects outage event logs generated by each meter in the target substation based on preset multi-source outage events. Then, based on the meter identifier, power supply phase, planned outage duration, actual outage duration, and outage duration deviation recorded in each outage event log, a spatiotemporal outage matrix is ​​constructed. Here, the power supply phase represents the phase of the power source used to supply power to the meter, as recorded in the low-voltage distribution network's topology file, and the outage duration deviation represents the absolute value of the difference between the planned and actual outage durations. By constructing the spatiotemporal outage matrix, the data recorded in each outage event log can be intuitively summarized, thus facilitating the subsequent topology file verification process. Furthermore, based on the spatiotemporal outage matrix, the phase-to-meter relationship and / or transformer-to-meter relationship are verified for each meter in the target substation. The topology file verification includes household phase relationship verification and household transformer relationship verification. Household phase relationship represents the attribution relationship between the household meter and the power output phase of the distribution transformer in the low-voltage distribution network, while household transformer relationship represents the attribution relationship between the household meter and the distribution transformer in the low-voltage distribution network. Through household phase relationship verification and / or household transformer relationship verification, the verification process goes beyond simply checking for errors in the topology attribution relationships recorded in the topology file. Even if the recorded topology attribution relationships are incorrect, it allows for a more precise analysis of the actual topology attribution relationships of the household meters. Therefore, this application provides a complete topology file verification process for low-voltage distribution networks. Attached Figure Description

[0058] 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.

[0059] Figure 1A flowchart illustrating the topology file verification method for a low-voltage distribution network provided in this application embodiment;

[0060] Figure 2 A schematic diagram of the verification logic for the topology file verification method of a low-voltage distribution network provided in this application embodiment;

[0061] Figure 3 A schematic diagram illustrating a scenario for the topology file verification method for a low-voltage distribution network provided in this application embodiment;

[0062] Figure 4 This is a schematic diagram of the structure of the topology verification device for a low-voltage distribution network provided in the embodiments of this application;

[0063] Figure 5 This is a hardware structure diagram of the electronic device provided in the embodiments of this application.

[0064] 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

[0065] 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 embodiments consistent with this application. Rather, they are merely examples of apparatuses and methods consistent with some aspects of this application as detailed in the appended claims.

[0066] The terms "first," "second," "third," "fourth," etc. (if present) in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that embodiments of the invention described herein can be implemented, for example, in orders other than those illustrated or described herein.

[0067] In this application, the terms "exemplary" or "for example" are used to indicate examples, illustrations, or descriptions. Any embodiment or design described as "exemplary" or "for example" in this application should not be construed as being more preferred or advantageous than other embodiments or designs. Specifically, the use of terms such as "exemplary" or "for example" is intended to present the relevant concepts in a specific manner.

[0068] 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.

[0069] In urban and rural power grids, low-voltage distribution networks typically include tens of thousands of distribution transformers, branch boxes, disconnectors, and meters, with complex topologies that change frequently.

[0070] Therefore, for ease of maintenance and management, low-voltage distribution networks are typically divided into multiple independent distribution areas. Each distribution area may include multiple branch boxes, disconnectors, and household meters, but has one and only one distribution transformer. The distribution transformer is used to supply power to all household meters and their associated electrical terminals within its distribution area.

[0071] As a key link in the operation and management of power systems, the topology file verification of low-voltage distribution networks aims to ensure the consistency between the power grid topology structure and the file data, especially the consistency between the actual topology affiliation of household meters and the topology affiliation of household meters recorded in the topology file.

[0072] In existing technology, before a power outage occurs, the control center of the transformer substation has prior knowledge of the meters within the substation that will experience power outages; these meters are known as the theoretical outage meters. During the power outage, the control center treats the meters that report outage information as the actual outage meters. Then, it compares the actual outage meters with the theoretical outage meters.

[0073] If the actual power outage meters match the theoretical power outage meters, then the low-voltage distribution network topology file is correct. If there are discrepancies between the actual and theoretical power outage meters, then the actual power outage meters that differ from the theoretical ones are identified, indicating that the information in the topology file for these discrepancies is incorrect.

[0074] However, existing technology only determines whether the actual topological affiliation of the household table matches the topological affiliation recorded in the topological archive. A complete topological archive verification requires further analysis to determine the specific actual topological affiliation of household tables with incorrect topological archive information.

[0075] Therefore, the existing topology verification process for low-voltage distribution networks is not complete enough.

[0076] Starting from the problems in existing technologies, the inventors considered two scenarios where errors in the topology profile information of household meters occur: First, the meter is located in one transformer substation but is actually connected to a distribution transformer in another substation, indicating an incorrect household-transformer relationship. Second, although the meter is connected to the distribution transformer in one substation, the phase of the power supply it is actually connected to is incorrect compared to the record in the topology profile, indicating an incorrect household-phase relationship. Based on this, the inventors proposed to verify the household-phase relationship and household-transformer relationship using the data included in the outage event logs generated by the household meters. Furthermore, considering that multiple household meters are distributed within a transformer substation, the inventors proposed constructing an outage spatiotemporal matrix based on the data in the outage time logs of each household meter to intuitively summarize the data. This allows for rapid and complete verification of the topology profiles of low-voltage distribution networks.

[0077] 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.

[0078] This application provides a method for verifying the topology profile of a low-voltage distribution network. Figure 1 This is a flowchart illustrating the topology file verification method for low-voltage distribution networks provided in this application embodiment. Figure 1 As shown, the topology file verification method for this low-voltage distribution network includes:

[0079] S101. Determine the target transformer substation in the low-voltage distribution network that is waiting to be verified; collect the outage event logs generated by each meter in the target transformer substation based on preset multi-source outage events.

[0080] Explanatory, the low-voltage distribution network is the object to be verified, specifically the power supply network range from the low-voltage side of the distribution transformer to each user's metering point. The verification work revolves around whether the topology file of the distribution area is consistent with the actual power supply relationship on site.

[0081] It should be understood that low-voltage distribution networks are typically divided into multiple distribution areas. A distribution area refers to the power supply range consisting of a single distribution transformer as its core, along with all the lines and equipment supplied by that transformer. That is, each distribution area is equipped with a corresponding distribution transformer, and the low-voltage side terminals of each distribution transformer are directly connected to the low-voltage main switch.

[0082] Therefore, the verification of topology files for low-voltage distribution networks is usually performed by transformer substation. This means that the topology files of each transformer substation within the low-voltage distribution network are verified separately, and then the verification results of the topology files of each transformer substation are summarized.

[0083] In this embodiment, the transformer substations awaiting verification in the low-voltage distribution network are considered as target substations, and planned power outage events are formulated for the target substations, or fault power outage events are monitored for the target substations. The planned power outage events and fault power outage events together constitute the preset multi-source power outage events for the target substations.

[0084] Planned power outage events represent pre-existing power outage records in the power distribution system due to maintenance, load shedding, line renovation, or orderly power outage arrangements. These records generally originate from maintenance plans, dispatch outage orders, or operation and maintenance instructions.

[0085] A power outage event is a record of a power outage caused by a line short circuit, equipment failure, external damage, or protection activation. It generally originates from line faults, equipment protection activation, low-voltage branch abnormalities, or interruption of power supply from the user's upstream side.

[0086] In this embodiment, planned power outage events and fault power outage events correspond to different outage causes and time characteristics, respectively, and together they form a complete observation basis for the operating status of household meters. Specifically, planned power outage events provide a relatively accurate time reference, facilitating the comparison between the planned power outage start time and the actual power outage start time. Fault power outage events, on the other hand, reflect the actual power loss process under sudden anomalies, making it easier to identify the impact of unplanned power outages on topology verification.

[0087] By incorporating planned power outages and fault power outages into the preset multi-source power outage events, data from different power outage sources can be compatible within the same verification framework. This provides stable input for subsequent phase consistency analysis, power outage duration deviation judgment, and household phase relationship verification and household transformer relationship verification, thereby improving the applicability and data reliability of low-voltage distribution network topology file verification.

[0088] In one possible implementation, planned power outage events and fault power outage events can be uniformly mapped to standard fields of the power outage event log, so that when constructing the power outage spatiotemporal matrix later, the user table identifier, power supply phase, planned power outage duration, actual power outage duration, and power outage duration deviation can be uniformly associated.

[0089] It should be noted that the low-voltage side terminals of a distribution transformer are typically standard three-phase four-wire output terminals, thus outputting three-phase (A-phase, B-phase, and C-phase) low-voltage AC power. This three-phase low-voltage AC power is distributed to different electrical terminals within the target distribution area after passing through the low-voltage main switch; that is, the A-phase power, B-phase power, and C-phase power are used to supply power to different electrical terminals within the target distribution area.

[0090] It should be understood that each electricity terminal is equipped with a household meter. The household meter is the main recorder of power outage information and the object for determining topology attribution. It can be a smart energy meter with event recording capabilities or a metering device that works in conjunction with the data acquisition terminal.

[0091] For planned power outages, the power system's master station issues the command to the target distribution area. Specifically, the master station first sends a task initiation command to the concentrator in the target distribution area, and the concentrator forwards the command to each meter. It is important to note that the master station cannot communicate directly with the individual meters within the target distribution area; communication must be relayed through the concentrator.

[0092] Explanatory, the task start command issued by the master station is used to inform the concentrators and meters of each household in the target area that the target area will be verified in advance, so as to ensure that each household meter enters the preparation state in advance, so as to record relevant data in real time when a planned power outage event occurs.

[0093] After the master station sends the task start command to the concentrator, it will continue to send a trip command to the low-voltage main switch of the target distribution area after a period of time. This trip command is used to control the low-voltage main switch to trip. It should be noted that the low-voltage main switch contains three single-pole switches, and these three single-pole switches correspond one-to-one with the three-phase power output of the distribution transformer.

[0094] In this embodiment, the three single-pole switches are tripped sequentially by phase. First, the master station sends a tripping command to the single-pole switch corresponding to phase A, causing a power outage for the terminal powered by phase A. Then, the master station sends a tripping command to the single-pole switch corresponding to phase B, causing a power outage for the terminal powered by phase B. Finally, the master station sends a tripping command to the single-pole switch corresponding to phase C, causing a power outage for the terminal powered by phase C.

[0095] Assume that the single-pole switch A corresponds to phase A of the power supply, the single-pole switch B corresponds to phase B of the power supply, and the single-pole switch C corresponds to phase C of the power supply. Clearly, the time difference Δt between the opening operations of the three single-pole switches A, B, and C is:

[0096] Δt = t_{k} - t_{k-1}

[0097] Where k represents three single-pole switches, with values ​​of 1, 2, and 3.

[0098] When k=3, t_{3} represents the opening time of single-pole switch C, t_{3-1} represents the opening time of single-pole switch B, and Δt represents the difference in opening time between single-pole switch B and single-pole switch C.

[0099] When k=2, t_{2} represents the opening time of single-pole switch B, t_{2-1} represents the opening time of single-pole switch A, and Δt represents the difference in opening time between single-pole switch A and single-pole switch B.

[0100] It is worth noting that when k=1, t_{1} represents the opening time of single-pole switch A, t_{1-1} represents the time when the master station sends the opening command to single-pole switch A, and t_{1-1}=t_{0}=0.

[0101] Understandably, the main station will pre-set the start and end times of planned power outage events. These planned power outage events refer to those specifically designated for single-pole switches A, B, and C. The start and end times are added to the task startup command and sent to the concentrator.

[0102] At the same time, the master station controls the single-pole switch A to open at the power outage start time set in advance by the power outage command. Then, it controls the single-pole switch B to open at the power outage start time set in advance by the power outage command. Finally, it controls the single-pole switch C to open at the power outage start time set in advance by the power outage command.

[0103] Finally, at the pre-set power outage termination time, the master station controls the closing of single-pole switches A, B, and C via a closing command. For clarity, single-pole switches A, B, and C must be opened sequentially by phase, but can be closed simultaneously.

[0104] For power outage events caused by faults, since these are not actively initiated outages, the master station cannot know in advance the planned start and end times of the outage. Therefore, this embodiment analyzes the outage phenomena within the target transformer area to first determine the fault point, and then detects the outage start and end times at the fault point.

[0105] It should be understood that when a power outage occurs, the fault point is used to locate the power source of the outage and serves as a reference for extracting the outage time.

[0106] Specifically, the process for determining the fault point is as follows: If only one user terminal in the target distribution area experiences a power outage, then that user terminal is identified as the fault point. If multiple user terminals in the target distribution area experience power outages, and the meters of the out-of-power user terminals are connected to the same disconnect switch, then that disconnect switch is identified as the fault point.

[0107] If the user terminal that is experiencing a power outage is equipped with a meter that belongs to multiple disconnect switches, but these multiple disconnect switches belong to the same branch box, then the branch box is identified as the fault point; if these multiple disconnect switches belong to multiple branch boxes, but the multiple branch boxes belong to the same outgoing switch, then the outgoing switch is identified as the fault point.

[0108] After identifying the fault location, the start and end times of the power outage are detected. It should be noted that, considering time drift caused by low clock battery voltage, this embodiment adds a power-on time synchronization broadcast when detecting the power outage end time. That is, at the instant power is restored (power outage ends) at the fault location, the concentrator broadcasts a standard time signal to the target station area. After the target station area calibrates its local clock, it re-detects the power outage end time of the fault location.

[0109] Based on the above, when the multi-source power outage event is preset as a planned power outage event, the power outage start time indicated by the planned power outage event is determined as the planned power outage start time, and the power outage end time indicated by the planned power outage event is determined as the planned power outage end time.

[0110] When a multi-source power outage event is pre-defined as a fault-based power outage event, the start time of the outage at the fault point is determined as the planned outage start time, and the end time of the outage at the fault point is determined as the planned outage end time. It is understandable that the absolute value of the difference between the planned outage start time and the planned outage end time represents the planned outage duration.

[0111] In addition, when the multi-source power outage event is preset as a planned power outage event, when the single-pole switch A / B / C is in the open state, the power terminals powered by the A / B / C phase power supply will experience a power outage. The meter equipped in these power terminals will record the actual power outage start time and the actual power outage end time of the power terminals.

[0112] Therefore, by collecting the actual power outage start time and actual power outage end time records of each household's electricity terminal within the target distribution area, the actual power outage duration of the electricity terminal can be determined as follows:

[0113] [d_A, d_B, d_C]=[T_{end}^A-T_{start}^A, T_{end}^B-T_{start}^B, T_{end}^C-T_{start}^C]

[0114] Wherein, d_A, d_B, and d_C represent the actual power outage durations of the electrical terminals powered by phase A, phase B, and phase C, respectively. T_{end}^A, T_{end}^B, and T_{end}^C represent the actual power outage start times of the electrical terminals powered by phase A, phase B, and phase C, respectively. T_{start}^A, T_{start}^B, and T_{start}^C represent the actual power outage end times of the electrical terminals powered by phase A, phase B, and phase C, respectively.

[0115] Similarly, when the multi-source power outage event is preset as a fault power outage event, the meter equipped with the power terminal where the power outage occurs will also record the actual start time and actual end time of the power outage in real time.

[0116] It should be understood that when the meter records the actual power outage termination time of the power consumption terminal, the concentrator will also broadcast a standard time signal to the meter. After the meter calibrates its local clock, it will re-record the actual power outage termination time of the power consumption terminal.

[0117] Obviously, the absolute value of the difference between the actual start time and the actual end time of the power outage is the actual power outage duration of the power user terminal.

[0118] Next, the meter will calculate the power outage duration deviation by combining the planned power outage duration and the actual power outage duration, and further generate a power outage event log. The power outage duration deviation is calculated as: |Planned power outage duration - Actual power outage duration|.

[0119] A power outage event log is a data record carrier generated by a customer meter after it senses a power outage. This log can at least be associated with a customer meter identifier and store the start and end times of the power outage or related fields that can be used to deduce the duration of the power outage. The customer meter identifier is used to uniquely identify each customer meter and can be implemented using the meter number, equipment asset code, communication address, or a unique number assigned by the master station, so that subsequent data processing can accurately map to the specific user.

[0120] Specifically, the power outage event logs generated by the household meter include, but are not limited to: household meter identifier, power supply phase, planned power outage start time, planned power outage end time, planned power outage duration, actual power outage start time, actual power outage end time, actual power outage duration, and power outage duration deviation.

[0121] Interpretive, the power supply phase designation represents the phase (A phase, B phase, or C phase) of the power source used to supply electricity to household meters and their corresponding terminals, as recorded in the topology profile of the low-voltage distribution network. Theoretically, household meters and their corresponding terminals located within a target distribution area are assumed to be powered by one phase of the power source provided by the distribution transformer of that target area.

[0122] S102. Based on the household meter identifier, power supply phase, planned power outage duration, actual power outage duration, and power outage duration deviation recorded in each power outage event log, construct a power outage spatiotemporal matrix.

[0123] In one possible implementation, the power outage spatiotemporal matrix adopts a two-dimensional matrix structure, with each matrix unit storing the user identifier, power supply phase, planned power outage duration, actual power outage duration, and power outage duration deviation of the corresponding user meter under the corresponding event.

[0124] Among them, the power supply phase can be directly read from the topology file and written into the matrix; the planned power outage duration can be obtained by subtracting the planned power outage start time from the planned power outage end time; the actual power outage duration can be obtained by subtracting the actual power outage start time from the actual power outage recovery time recorded by the household meter; and the power outage duration deviation can be obtained by subtracting the actual power outage duration from the planned power outage duration.

[0125] For example, assuming there are two power terminals in the target distribution area, there are two corresponding meters. Both meters have generated outage event logs. Based on this, the outage spatiotemporal matrix constructed in this step is as follows:

[0126]

[0127] In the power outage time-space matrix, the first column is the household meter identifier, the second column is the power supply phase, the third column is the planned power outage duration, the fourth column is the actual power outage duration, and the fifth column is the power outage duration deviation.

[0128] In detail, the purpose of power outage duration deviation is to establish a unified and quantitative link between theoretical power outage information at the planning level and actual perceived information at the meter level. When the power outage duration deviation is small, it indicates that the data attribution is relatively consistent with the actual power supply impact range. When the power outage duration deviation exceeds the threshold, it indicates that there may be errors in the phase attribution of the meter, the transformer attribution, abnormal event records, or excessive equipment clock deviation.

[0129] As can be seen, the power outage spatiotemporal matrix is ​​used to organize the spatial attribution information and time response information of each household meter in different power outage events into a computable data structure, thereby supporting subsequent batch verification and analysis.

[0130] S103. Based on the power outage time-space matrix, perform household phase relationship verification and / or household transformer relationship verification on each household meter in the target transformer area.

[0131] It should be understood that although the power outage spatiotemporal matrix includes both planned and actual power outage durations, the planned power outage duration can be used to trace back to the planned power outage start and end times, and the actual power outage duration can be used to trace back to the actual power outage start and end times.

[0132] Specifically, based on the planned power outage start time corresponding to the planned power outage duration in the power outage time-space matrix, and the actual power outage start time corresponding to the actual power outage duration, phase consistency analysis is performed on the household meters to obtain the phase consistency analysis results.

[0133] For clarity, both the planned and actual power outage start times are analyzed and compared using a unified time base. This unified time base can be the main station server time, the network time synchronized by the concentrator, or the pre-calibrated local time.

[0134] Therefore, to avoid misjudgment caused by format differences, before performing consistency analysis, the planned power outage start time and the actual power outage start time can be converted into timestamp representations of the same granularity before performing equivalence judgment.

[0135] When the planned power outage start time and the actual power outage start time are the same, the phase consistency analysis result of the household meter is determined to be consistent, which means that the power supply phase of the household meter recorded in the topology file of the low-voltage distribution network is correct.

[0136] It is important to note that correct phase identification does not necessarily mean correct distribution area identification. Conversely, if the planned power outage start time and the actual power outage start time are inconsistent, the phase identification consistency analysis result for the household meter is determined to be inconsistent, meaning that the power supply phase identification recorded in the low-voltage distribution network topology file for that household meter is incorrect.

[0137] It should be noted that, theoretically, each household meter within the target distribution area will be connected to a specific phase (phase A, phase B, or phase C) of the power supply output from the distribution transformer in the target distribution area. Therefore, the topology file will record the phase of power supply connected to each household meter, i.e., the power supply phase.

[0138] However, in reality, the phase of the power supply actually connected to the meter in the target area may not be the same as the phase of the power supply recorded in the topology file, or the meter in the target area may actually be connected to the distribution transformer in another area.

[0139] Therefore, after obtaining the phase consistency analysis results, this step combines the phase consistency analysis results with the power outage duration deviation in the power outage time-space matrix to perform household phase relationship verification and / or household transformer relationship verification for each household meter in the target transformer area.

[0140] The topology file verification includes household phase relationship verification and household transformer relationship verification. The household phase relationship represents the affiliation between the household meter and the power output phase of the distribution transformer in the low-voltage distribution network, while the household transformer relationship represents the affiliation between the household meter and the distribution transformer in the low-voltage distribution network.

[0141] Specifically, Figure 2 A schematic diagram of the verification logic for the topology file verification method for low-voltage distribution networks provided in this application embodiment is shown below. Figure 2 As shown, the process first determines whether to perform a household-to-meter relationship check or a household-to-transformer relationship check based on the relationship between the power outage duration deviation and the preset threshold. The preset threshold is used to distinguish whether the power outage duration deviation is abnormal. It is usually obtained by statistical analysis of historical power outage data of the target transformer area and can be set comprehensively according to the clock drift range of the metering device, the communication delay range, and the planned power outage execution error.

[0142] If the power outage duration deviation is less than or equal to a preset threshold, it means that the household meter is connected to the distribution transformer of the target area. At this point, further analysis of phase consistency results is conducted to determine whether to proceed with the household phase relationship verification or directly determine that the topology file is correct.

[0143] If the phase consistency analysis result indicates that the phases of the meters are consistent, then the power supply phases of the meters recorded in the topology file are correct, meaning the topology file is correct. However, if the phase consistency analysis result indicates that the phases of the meters are inconsistent, it means that the power supply phases of the meters recorded in the topology file are incorrect, and in this case, a phase relationship verification of the meters is required.

[0144] It should be understood that the household phase relationship verification can be based on the consistency of the meter's response during the power outage period, the synchronization of power outages for meters in the same phase, and the correspondence with the output phase of the distribution transformer to identify whether the meter is connected to the wrong phase.

[0145] If the power outage duration deviation exceeds a preset threshold, it directly indicates that the meter is not connected to the distribution transformer in the target area, but may be connected to a distribution transformer in another area. In this case, regardless of whether the phase consistency analysis indicates that the meter's phase is consistent, further verification of the meter-transformer relationship is required. By verifying the attribution relationship between the meter and the distribution transformer, it is possible to identify situations such as cross-transformer access, incorrect file registration, or outdated information during distribution area relocation.

[0146] It should be noted that after determining the distribution transformer to which the meter belongs through the household-to-transformer relationship verification, it is necessary to further verify the household-to-phase relationship of the meter to determine the power supply phase connected to the meter in the distribution transformer to which it belongs.

[0147] Therefore, whether the meter is connected to the distribution transformer in the target area directly determines whether to perform a meter-to-meter relationship verification or a meter-to-transformer relationship verification. If a meter-to-transformer relationship verification is required, a meter-to-meter relationship verification is also necessary.

[0148] The process of verifying the phase relationship of a customer's meter is as follows: Among the three planned power outage start times associated with phase A, phase B, and phase C power supplies, determine the target planned power outage start time that matches the actual power outage start time recorded on the customer's meter. The phase of the power supply associated with this target planned power outage start time is the phase of the power supply actually connected to the customer's meter.

[0149] The process of verifying the household-transformer relationship for household meters is as follows: From multiple planned power outage durations associated with other transformer substations in the low-voltage distribution network, a target planned power outage duration is determined whose absolute value of the difference between the target planned power outage duration and the actual power outage duration recorded by the household meter is less than or equal to a preset threshold. The other transformer substations associated with this target planned power outage duration are the substations actually connected to the household meter. Then, using the aforementioned household-transformer relationship verification process, the phase of the power supply connected to the actually connected substation is further determined.

[0150] As can be seen, the first verification result of the household-to-transformer relationship verification refers to the actual topological affiliation of the household meter in the target transformer area, that is, the phase of the power supply actually connected to the household meter in the target transformer area. The second verification result of the household-to-transformer relationship verification refers to the actual topological affiliation of the household meter in other transformer areas, that is, the phase of the power supply actually connected to the household meter in other transformer areas. Finally, based on the actual topological affiliation of the household meter indicated by the first verification result and / or the second verification result, the topology file of the low-voltage distribution network is corrected.

[0151] In actual implementation, after completing the household-phase relationship verification and / or household-transformer relationship verification, the system receives the first verification result of the household-phase relationship verification and / or the second verification result of the household-transformer relationship verification, and parses the household meter identifier, the phase to which it belongs, the identifier of the distribution transformer to which it belongs, and the corresponding verification conclusion contained in the first verification result and / or the second verification result.

[0152] If the first verification result indicates that the phase assignment of a meter for a user is inconsistent with the record in the archive, then the phase information corresponding to that meter is written into the topology archive. If the second verification result indicates that the distribution transformer corresponding to that meter is inconsistent with the record in the archive, then the transformer assignment information for that meter is updated in the topology archive.

[0153] It is worth noting that, in cases where both the first and second verification results are obtained simultaneously, the attribution relationship of the same household meter can be cross-confirmed based on the consistency of the results, and the original file content can be overwritten with the confirmed actual topology attribution relationship, thereby completing the correction of the low-voltage distribution network topology file.

[0154] Once the topology file is corrected, the association records between customer meters and phases, and between customer meters and distribution transformers within the transformer area can be updated synchronously. The differences before and after the correction will be generated into a change log for future traceability. This correction process can directly feed back the true attribution relationship obtained from power outage event verification to the archive, avoiding the long-term retention of incorrect wiring relationships in historical files.

[0155] In conclusion, Figure 3 A schematic diagram illustrating a scenario for the low-voltage distribution network topology file verification method provided in this application embodiment, as shown below. Figure 3As shown, the topology file verification method for low-voltage distribution networks in this embodiment can be divided into three stages: power outage event detection stage, topology file verification stage, and topology file correction stage.

[0156] The power outage event perception stage includes the issuance or occurrence of preset multi-source power outage events and the collection of relevant power outage data by household meters. The topology file verification stage includes the construction of the power outage spatiotemporal matrix, the verification of household-to-household relationship and / or household-to-transformer relationship of household meters. The topology file correction stage includes the correction of the topology file of household meters.

[0157] The low-voltage distribution network topology file verification method provided in this application identifies the target transformer substations awaiting verification in the low-voltage distribution network and collects outage event logs generated by each meter in the target substation based on planned or fault outage events. Then, based on the meter identifier, power supply phase, planned outage duration, actual outage duration, and outage duration deviation recorded in each outage event log, a spatiotemporal outage matrix is ​​constructed. Here, the power supply phase represents the phase of the power source used to supply power to the meter, as recorded in the low-voltage distribution network topology file, and the outage duration deviation represents the absolute value of the difference between the planned and actual outage durations. By constructing the spatiotemporal outage matrix, the data recorded in each outage event log can be intuitively summarized, thus facilitating the subsequent topology file verification process. Furthermore, the planned outage start time corresponding to the planned outage duration in the spatiotemporal outage matrix and the actual outage start time corresponding to the actual outage duration are determined. By comparing the planned and actual outage start times, phase consistency analysis is performed on the meters. If the planned power outage start time and the actual power outage start time are the same, the phase consistency analysis result for the meter is "phase consistent". If the planned power outage start time and the actual power outage start time are different, the phase consistency analysis result for the meter is "phase inconsistent". Next, if the power outage duration deviation in the power outage spatiotemporal matrix is ​​less than or equal to a preset threshold, and the phase consistency analysis result is "phase inconsistent", then the meter undergoes a phase-to-terminal relationship verification. If the power outage duration deviation is greater than the preset threshold, then the meter undergoes a transformer-to-terminal relationship verification. Through phase-to-terminal relationship verification and / or transformer-to-terminal relationship verification, the analysis no longer merely focuses on whether the topological attribution of the meter recorded in the topology file is correct. Instead, even if the topological attribution of the meter recorded in the topology file is incorrect, it can further clarify the specific actual topological attribution of the meter. Therefore, this application provides a complete topology file verification process for low-voltage distribution networks.

[0158] Figure 4 This is a schematic diagram of the structure of the topology file verification device for a low-voltage distribution network provided in the embodiments of this application, as shown below. Figure 4As shown, the topology file verification device 400 for the low-voltage distribution network includes: a determination module 401, a data acquisition module 402, a construction module 403, and a verification module 404.

[0159] Among them, the determination module 401 is used to determine the target transformer area waiting to be verified in the low-voltage distribution network;

[0160] The data acquisition module 402 is used to collect power outage event logs generated by each household meter in the target transformer area based on preset multi-source power outage events;

[0161] Module 403 is used to construct a power outage spatiotemporal matrix based on the meter identifier, power supply phase, planned power outage duration, actual power outage duration, and power outage duration deviation recorded in each power outage event log. Among them, the power supply phase represents the phase of the power source used to supply power to the meter recorded in the topology file of the low-voltage distribution network, and the power outage duration deviation represents the absolute value of the difference between the planned power outage duration and the actual power outage duration.

[0162] The verification module 404 is used to perform household phase relationship verification and / or household transformer relationship verification on each household meter in the target distribution area according to the power outage spatiotemporal matrix. Among them, the topology file verification includes household phase relationship verification and household transformer relationship verification. The household phase relationship represents the affiliation relationship between the household meter and the power output phase of the distribution transformer in the low-voltage distribution network, and the household transformer relationship represents the affiliation relationship between the household meter and the distribution transformer in the low-voltage distribution network.

[0163] In one possible design, the verification module 404 includes:

[0164] The determination submodule 4041 is used to determine the planned power outage start time corresponding to the planned power outage duration in the power outage time-space matrix, and the actual power outage start time corresponding to the actual power outage duration.

[0165] Analysis submodule 4042 is used to perform phase consistency analysis on household meters based on the planned power outage start time and the actual power outage start time, and to determine the phase consistency analysis results;

[0166] The verification submodule 4043 is used to perform household phase relationship verification and / or household transformer relationship verification on each household meter in the target transformer area based on the phase consistency analysis results and the power outage duration deviation in the power outage time-space matrix.

[0167] In one possible design, the analysis submodule 4042 includes: a first determining component for:

[0168] If the planned power outage start time and the actual power outage start time are the same, then the phase consistency analysis result of the household meter is determined to be phase consistent.

[0169] If the planned power outage start time and the actual power outage start time are inconsistent, then the phase consistency analysis result of the household meter is determined to be inconsistent.

[0170] In one possible design, the verification submodule 4043 includes:

[0171] The verification component is used to verify the phase relationship of the household meter if the power outage duration deviation in the power outage time-space matrix is ​​less than or equal to a preset threshold and the phase consistency analysis result indicates that the phases of the household meter are inconsistent.

[0172] The second determining component is used to determine that the topology file of the low-voltage distribution network is correct if the power outage duration deviation in the power outage time-space matrix is ​​less than or equal to a preset threshold and the phase consistency analysis result indicates that the phases of the meters are consistent; wherein, the topology file indicates the topology affiliation of each meter.

[0173] The verification component is also used to verify the household meter relationship if the deviation of the power outage duration in the power outage time-space matrix is ​​greater than a preset threshold.

[0174] In one possible design, the verification submodule 4043 also includes:

[0175] The acquisition component is used to acquire the first verification result of the household relationship verification and / or the second verification result of the household-change relationship verification.

[0176] The correction component is used to correct the topology profile of the low-voltage distribution network based on the actual topology affiliation of the household meters indicated by the first verification result and / or the second verification result.

[0177] In one possible design, the preset multi-source power outage events include planned power outage events and fault power outage events.

[0178] In one possible design, module 401 is also used for:

[0179] When a multi-source power outage event is preset as a planned power outage event, the power outage start time indicated by the planned power outage event is determined as the planned power outage start time, and the power outage end time indicated by the planned power outage event is determined as the planned power outage end time.

[0180] When the multi-source power outage event is preset as a fault power outage event, the fault point is determined; the power outage start time of the fault point is determined as the planned power outage start time, and the power outage end time of the fault point is determined as the planned power outage end time.

[0181] The absolute value of the difference between the planned start time and the planned end time of the power outage is determined as the planned power outage duration;

[0182] The data acquisition module 402 is also used to collect the actual power outage start time and actual power outage end time of the household meter.

[0183] The determination module 401 is also used to determine the absolute value of the difference between the actual power outage start time and the actual power outage end time, which is the actual power outage duration; and to determine the absolute value of the difference between the planned power outage duration and the actual power outage duration, which is the power outage duration deviation.

[0184] The topology file verification device for low-voltage distribution networks provided in this application embodiment can be used to execute the topology file verification method for low-voltage distribution networks in any of the above embodiments. Its implementation principle and technical effect are similar, and will not be described again here.

[0185] It should be noted that the division of the various modules in the above device is merely a logical functional division. In actual implementation, they can be fully or partially integrated into a single physical entity, or they can be physically separated. Furthermore, these modules can be implemented entirely in software via processing element calls; they can be fully implemented in hardware; or some modules can be implemented in software via processing element calls, while others are implemented in hardware. Additionally, these modules can be fully or partially integrated together, or implemented independently. The processing element here can be an integrated circuit with signal processing capabilities. During implementation, each step of the above method or each of the above modules can be completed through the integrated logic circuits in the hardware of the processor element or through software instructions.

[0186] Figure 5 This is a schematic diagram of the structure of an electronic device provided in an embodiment of this application. Figure 5 As shown, the electronic device may include: transceiver 51, processor 52, and memory 53.

[0187] Processor 52 executes computer execution instructions stored in memory, causing processor 52 to perform the scheme in the above embodiments. Processor 52 can be a general-purpose processor, including a central processing unit (CPU), a network processor (NP), etc.; it can also be a digital signal processor (DSP), an application-specific integrated circuit (ASIC), a field-programmable gate array (FPGA), or other programmable logic devices, discrete gate or transistor logic devices, or discrete hardware components.

[0188] The memory 53 is connected to the processor 52 via the system bus and completes communication between them. The memory 53 is used to store computer program instructions.

[0189] Transceiver 51 can be used to communicate and interact with other devices.

[0190] The system bus can be a Peripheral Component Interconnect (PCI) bus or an Extended Industry Standard Architecture (EISA) bus, etc. The system bus can be divided into address bus, data bus, control bus, etc. For ease of representation, only one thick line is used in the diagram, but this does not indicate that there is only one bus or one type of bus. Transceivers are used to enable communication between database access devices and other computers (e.g., clients, read-write libraries, and read-only libraries). Memory may include random access memory (RAM) and may also include non-volatile memory.

[0191] The electronic device provided in this application embodiment can be used to execute the method provided in any of the above embodiments. Its implementation principle and technical effect are similar, and will not be described again here.

[0192] This application also provides a computer-readable storage medium storing computer instructions that, when executed on a computer, cause the computer to perform the methods provided in any of the above embodiments.

[0193] This application also provides a computer program product, which includes a computer program stored in a computer-readable storage medium. At least one processor can read the computer program from the computer-readable storage medium, and when the at least one processor executes the computer program, it can implement the method provided in any of the above embodiments.

[0194] In the several embodiments provided in this application, it should be understood that the disclosed devices and methods can be implemented in other ways. For example, the device embodiments described above are merely illustrative; for instance, the division of modules is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple modules may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be indirect coupling or communication connection through some interfaces, devices, or modules, and may be electrical, mechanical, or other forms.

[0195] The modules described as separate components may or may not be physically separate. The components shown as modules 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 modules can be selected to implement the solution of this embodiment according to actual needs.

[0196] Furthermore, the functional modules in the various embodiments of this application can be integrated into one processing unit, or each module can exist physically separately, or two or more modules can be integrated into one unit. The unit composed of the above modules can be implemented in hardware or in the form of hardware plus software functional units.

[0197] The integrated modules described above, implemented as software functional modules, can be stored in a computer-readable storage medium. These software functional modules, stored in a storage medium, include several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) or processor to execute some steps of the methods of the various embodiments of this application.

[0198] It should be understood that the aforementioned processor can be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), etc. A general-purpose processor can be a microprocessor or any conventional processor. The steps of the method disclosed in this invention can be directly manifested as execution by a hardware processor, or execution by a combination of hardware and software modules within the processor.

[0199] The memory may include high-speed RAM, and may also include non-volatile storage (NVM), such as at least one disk storage device, and may also be a USB flash drive, external hard drive, read-only memory, disk or optical disc, etc.

[0200] 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.

[0201] The aforementioned 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 storage medium can be any available medium that can be accessed by a general-purpose or special-purpose computer.

[0202] An exemplary storage medium is coupled to a processor, enabling the processor to read information from and write information to the storage medium. Alternatively, the storage medium can be an integral part of the processor. The processor and storage medium can reside in application-specific integrated circuits (ASICs). Alternatively, the processor and storage medium can exist as discrete components in an electronic control unit or main control device.

[0203] 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.

[0204] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of this application, and are not intended to limit them. Although this application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some or all of the technical features therein. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of this application.

Claims

1. A method for verifying the topology profile of a low-voltage distribution network, characterized in that, include: Identify the target transformer substations in the low-voltage distribution network awaiting verification; Collect outage event logs generated by each household meter in the target transformer area based on preset multi-source power outage events; Based on the meter identifier, power supply phase, planned outage duration, actual outage duration, and outage duration deviation recorded in each outage event log, a power outage spatiotemporal matrix is ​​constructed; wherein, the power supply phase represents the phase of the power source used to supply power to the meter as recorded in the topology file of the low-voltage distribution network, and the outage duration deviation represents the absolute value of the difference between the planned outage duration and the actual outage duration; Based on the aforementioned power outage spatiotemporal matrix, the phase relationship verification and / or transformer relationship verification are performed on each meter in the target distribution area; wherein, the topology file verification includes phase relationship verification and transformer relationship verification, the phase relationship of the meter represents the affiliation relationship between the meter and the power output phase of the distribution transformer in the low-voltage distribution network, and the transformer relationship represents the affiliation relationship between the meter and the distribution transformer in the low-voltage distribution network.

2. The method according to claim 1, characterized in that, Based on the aforementioned power outage spatiotemporal matrix, perform household-to-household relationship verification and / or household-to-transformer relationship verification on each meter in the target transformer area, including: Determine the planned power outage start time corresponding to the planned power outage duration in the power outage spatiotemporal matrix, and the actual power outage start time corresponding to the actual power outage duration; based on the planned power outage start time and the actual power outage start time, perform phase consistency analysis on the household meters, and determine the phase consistency analysis results; Based on the phase consistency analysis results and the power outage duration deviation in the power outage time-space matrix, the phase relationship verification and / or transformer relationship verification are performed on each household meter in the target transformer area.

3. The method according to claim 2, characterized in that, Based on the planned power outage start time and the actual power outage start time, phase consistency analysis is performed on the household meters, and the phase consistency analysis results are determined, including: If the planned power outage start time is the same as the actual power outage start time, then the phase consistency analysis result of the household meter is determined to be phase consistent. If the planned power outage start time and the actual power outage start time are inconsistent, then the phase consistency analysis result of the household meter is determined to be inconsistent.

4. The method according to claim 2, characterized in that, Based on the phase consistency analysis results and the outage duration deviation in the outage spatiotemporal matrix, the phase relationship verification and / or transformer relationship verification are performed on each meter in the target transformer area, including: If the power outage duration deviation in the power outage time-space matrix is ​​less than or equal to a preset threshold, and the phase consistency analysis result indicates that the phases of the household meters are inconsistent, then the household meters are checked for phase relationship. If the power outage duration deviation in the power outage time-space matrix is ​​less than or equal to a preset threshold, and the phase consistency analysis result indicates that the phases of the meters are consistent, then the topology file of the low-voltage distribution network is determined to be correct; wherein, the topology file indicates the topology affiliation of each meter. If the power outage duration deviation in the power outage time-space matrix is ​​greater than the preset threshold, then the household meter will be checked for household-transformer relationship.

5. The method according to claim 4, characterized in that, The method further includes: Obtain the first verification result of the household relationship verification and / or the second verification result of the household change relationship verification; Based on the actual topology attribution of the household meters indicated by the first verification result and / or the second verification result, the topology file of the low-voltage distribution network is corrected.

6. The method according to any one of claims 1 to 5, characterized in that, The preset multi-source power outage events include planned power outage events and fault power outage events.

7. The method according to claim 6, characterized in that, The method further includes: When the preset multi-source power outage event is the planned power outage event, the power outage start time indicated by the planned power outage event is determined as the planned power outage start time, and the power outage end time indicated by the planned power outage event is determined as the planned power outage end time. When the preset multi-source power outage event is the fault power outage event, the fault point is determined; the power outage start time of the fault point is determined as the planned power outage start time, and the power outage end time of the fault point is determined as the planned power outage end time. The absolute value of the difference between the planned power outage start time and the planned power outage end time is determined as the planned power outage duration; the actual power outage start time and actual power outage end time are collected from the household meters, and the absolute value of the difference between the actual power outage start time and the actual power outage end time is determined as the actual power outage duration; the absolute value of the difference between the planned power outage duration and the actual power outage duration is determined as the power outage duration deviation.

8. A topology verification device for a low-voltage distribution network, characterized in that, include: The determination module is used to identify target transformer areas awaiting verification in the low-voltage distribution network. The data acquisition module is used to collect power outage event logs generated by each household meter in the target transformer area based on preset multi-source power outage events; The construction module is used to construct a power outage spatiotemporal matrix based on the meter identifier, power supply phase, planned power outage duration, actual power outage duration, and power outage duration deviation recorded in each power outage event log; wherein, the power supply phase represents the phase of the power source used to supply power to the meter as recorded in the topology file of the low-voltage distribution network, and the power outage duration deviation represents the absolute value of the difference between the planned power outage duration and the actual power outage duration; The verification module is used to perform household phase relationship verification and / or household transformer relationship verification on each household meter in the target distribution area according to the power outage spatiotemporal matrix; wherein, the topology file verification includes household phase relationship verification and household transformer relationship verification, the household phase relationship represents the affiliation relationship between the household meter and the power output phase of the distribution transformer in the low-voltage distribution network, and the household transformer relationship represents the affiliation relationship between the household meter and the distribution transformer in the low-voltage distribution network.

9. An electronic device, characterized in that, include: A processor, and a memory communicatively connected to the processor; The memory stores computer-executed instructions; The processor executes the computer execution instructions stored in the memory to implement the topology file verification method for low-voltage distribution networks as described in any one of claims 1 to 7.

10. 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 topology file verification method for a low-voltage distribution network as described in any one of claims 1 to 7.

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