Main distribution micro cooperative fault processing method and system

Abstract

The invention discloses a main-distribution-micro-cooperation fault processing method and system, and belongs to the technical field of power system dispatching and fault handling, and the method comprises the steps: carrying out the fault perception and risk analysis of main-distribution-micro-cooperation after a fault is triggered, and generating an event fault event; through grid identification and power-loss monitoring, analyzing a power-loss condition and determining a power-loss influence level; generating an alarm event based on the event fault event and the grid identification and power loss monitoring result; and according to the alarm event and the power loss condition analysis result, generating a main-distribution-micro cooperative processing scheme, and supporting visual layered display. According to the method, the defects of fragmentation, low cooperation efficiency and scattered disposal schemes of main and distribution micro fault disposal in the prior art are overcome, the fault positioning accuracy, provincial and regional cooperation efficiency and the scientificity of the disposal schemes are remarkably improved, and the influence of faults on safe operation of a power grid and power supply of users is effectively reduced; the method is suitable for a main and distribution micro-grid fault handling scene containing distributed resources.

Description

Technical Field

[0001] This invention belongs to the field of power system dispatching and fault handling technology, and particularly relates to a method and system for handling main and distribution micro-coordinated faults. Background Technology

[0002] With the large-scale integration of distributed power sources (such as photovoltaic and wind power), the power system is gradually forming a complex pattern of coordinated operation of the "main grid-distribution grid-microgrid" (hereinafter referred to as "main grid-distribution-microgrid"). Currently, provincial dispatch centers are mainly responsible for monitoring and fault handling of the main grid at voltage levels of 220kV and above, while regional dispatch centers are mainly responsible for the management of the distribution grid at voltage levels of 10kV and above and microgrids. There are significant shortcomings in data exchange and collaborative fault analysis between the two.

[0003] 1. Fragmented fault perception: The main and minor fault information is collected independently by the provincial and local dispatch centers, lacking a unified event-based integration mechanism. Especially in the case of cascading faults, it is easy to misjudge multiple fault events or the nature of a single fault, resulting in delays in fault location.

[0004] 2. Inefficient grid zoning management: The existing dispatching system does not perform fine-grained grid division based on grid structure, power source and load characteristics. After a fault occurs, it is difficult to quickly locate the affected area, and the efficiency of power outage ratio statistics and power supply path analysis is low.

[0005] 3. Low efficiency of provincial and local coordination: The alarm information and power outage range analysis results of the provincial and local dispatch centers are mostly in a passive query mode, lacking an active uploading and automatic matching mechanism, which leads to the lag in fault impact analysis and the untimely transmission of power loss information for important users.

[0006] 4. Dispersed handling solutions: The handling of main grid faults (such as unit regulation and mode adjustment) and distribution network / microgrid handling (such as load transfer and equipment power restoration) are executed independently by provincial and local dispatch centers, respectively. There is no unified and coordinated handling solution, which makes it difficult to meet the needs of efficient regulation and control of distributed resources. Summary of the Invention

[0007] Purpose of the invention: The purpose of this invention is to provide a method and system for handling faults in a coordinated manner between primary and secondary dispatch centers, which can realize fault collaborative perception, refined grid management, efficient information exchange between provinces and regions, and collaborative decision-making.

[0008] Technical solution: The main-supplier-micro-cooperative fault handling method includes:

[0009] Dispatch agencies at all levels collect fault perception information within their corresponding dispatch areas and generate initial fault events; based on fault occurrence events and topological distance, the initial fault events of each level of the power grid are integrated and merged to obtain event-based fault events, which include event IDs, and fault impact analysis is performed.

[0010] Establish a power grid mesh model and perform automatic network identification, including: assigning main grid and distribution network equipment to corresponding meshes, merging meshes in multi-transformer scenarios, and generating unique mesh identifiers; updating the mesh division of equipment in real time; and labeling the mesh ID to which the event-based fault event belongs based on the power grid mesh model.

[0011] Analyze the power outage situation and determine the impact level of the power outage, and send it to the superior dispatching agency; based on the event ID and grid ID, automatically match the power outage situation and the determined impact level of the power outage with the local fault information of the superior dispatching agency. If the match is successful, it is merged into a unified alarm event; if the match fails, a separate alarm is issued.

[0012] Perform grid power loss statistics and generate a power loss analysis report;

[0013] Based on the unified alarm events and power outage analysis reports, the higher-level dispatching agency generates a unified main, distribution, and micro-distribution collaborative handling plan.

[0014] Optionally, the method further includes: displaying at least one of the following information according to the scheduling level: fault perception information, event-based fault events, grid power outage statistics, and main-distribution-micro collaborative handling scheme; the displayed information supports data linkage query between levels.

[0015] Optionally, the fault impact analysis includes:

[0016] Real-time response to fault outage range analysis service requests, restoration of the normal operation section of the power grid before the fault, and statistics on the energized status of equipment and load operation information within the section;

[0017] Based on the fault switch action sequence, the normally operating sections are set sequentially to obtain the fault sections. By comparing the equipment status of the normally operating sections and the fault sections, and combining network topology search, the power outage equipment, load loss, affected important users and distributed power information within the fault impact range are statistically analyzed, and the analysis results are output.

[0018] Optionally, establishing the power grid model includes:

[0019] Based on the power grid structure, power supply structure, and load characteristics, starting from the low-voltage side of the 220kV main transformer, a topology search is performed along the voltage level descent direction to the boundary equipment of the main grid model, dividing the entire network into several grids; the grid definition follows the following rules:

[0020] (a) Identify the 220kV and below substations included within the grid;

[0021] (b) Using the low-voltage side or medium-voltage side of the transformer in the substation as the grid boundary, all subordinate devices below the boundary are automatically identified to the same grid in terms of topology;

[0022] (c) Communication within and between grids is adjusted via the low-pressure side.

[0023] Optionally, the simultaneous mesh merging in multi-transformer scenarios to generate a unique mesh identifier includes:

[0024] Using the 220kV main transformer as the boundary device, a network topology search is performed downwards to assign devices within the boundary to the same grid. If other 220kV main transformers are encountered during the topology search, the two grids are merged and marked. The marking includes: a merge identifier, the grid ID of the relevant interconnected area, and is written into the grid field of the main network device model table.

[0025] Optionally, the mesh partitioning of the real-time update device includes:

[0026] If the grid of the main grid equipment changes, the distribution network system is notified to divide the grid of the distribution network equipment; if the grid of the main grid equipment does not change, the grid is automatically identified in a cycle to ensure that the grid division matches the grid operation status in real time.

[0027] Optionally, the step of performing grid power loss statistics and generating a power loss analysis report includes:

[0028] The grid is automatically identified periodically, and grid sections are cached.

[0029] After a failure occurs, a mesh model generation request is received, and the last mesh section before the failure is retrieved from the cache.

[0030] Based on all power-loss devices in the fault event, search the affected grid, extract all device models of the affected grid, and form the affected grid model file;

[0031] The proportion of power-loss devices within the affected grid is statistically analyzed, and a power supply path map is generated based on the device topology.

[0032] The master-slave micro-coordinated fault handling system includes: an upper-level scheduling subsystem and a lower-level scheduling subsystem, which are communicatively connected; wherein,

[0033] The higher-level scheduling subsystem includes:

[0034] The first layered event perception module is used to collect fault perception information of the power grid within the scope of the upper-level dispatch and generate the first initial fault event.

[0035] The collaborative event-based module is used to integrate and merge the initial fault events of each level of the power grid based on the first initial fault event and the second initial fault event, and the fault occurrence event and topological distance to generate event-based fault events.

[0036] The grid identification service module is used to establish a power grid model, perform automatic network identification, and serve as the basis for the event rating module to analyze power outages. It includes: assigning main grid and distribution network equipment to corresponding grids, merging grids in multi-transformer scenarios, and generating unique grid identifiers; updating the grid division of equipment in real time; and labeling the grid ID to which the event-based fault event belongs based on the power grid model.

[0037] The information coordination module is used to receive information sent by the lower-level scheduling subsystem, and automatically match it with local fault information to merge it into a unified alarm event, or to issue a separate alarm.

[0038] The power loss analysis module is used to perform grid power loss statistics and generate power loss analysis reports.

[0039] The handling plan generation module is used to generate a unified main-distributor-micro-system collaborative handling plan based on the unified alarm event and power failure analysis report.

[0040] The lower-level scheduling subsystem includes:

[0041] The second-level event perception module is used to collect fault perception information of the power grid within the lower-level dispatch range and generate a second initial fault event.

[0042] The fault impact analysis module is used to perform fault impact analysis on the second initial fault event;

[0043] The event rating module is used to analyze power outages, determine the impact level of power outages, and report the results to the higher-level dispatching agency.

[0044] The information proactive uploading module is used to proactively upload the second initial fault event, the fault impact analysis results, and the power outage impact level to the superior scheduling subsystem.

[0045] Optionally, the upper-level dispatching subsystem is a provincial dispatching subsystem, deployed in provincial dispatching monitoring zones I and III; the lower-level dispatching subsystem is a regional dispatching subsystem, deployed in regional dispatching monitoring zone I.

[0046] Optionally, the system further includes: an interface module for displaying at least one of the following information according to the scheduling hierarchy: fault perception information, event-based fault events, grid power outage statistics, and main-distribution-micro collaborative handling schemes; the displayed information supports data linkage query between levels.

[0047] Beneficial effects: Compared with the prior art, the present invention has the following significant advantages:

[0048] 1. More accurate fault perception: By integrating hierarchical event perception and collaborative event-based integration, the problem of fragmented information on main and auxiliary minor faults is solved. Especially in the case of cascading faults, it can realize the location of multiple device faults and single events, thereby improving the accuracy and efficiency of fault location.

[0049] 2. More precise power failure monitoring: Based on the grid division and automatic identification of the 220kV main transformer, combined with power failure ratio analysis and automatic mapping, the affected area of ​​the fault can be quickly located, and the distribution of power failure equipment and power supply path can be displayed intuitively, providing accurate basis for fault handling.

[0050] 3. More efficient provincial-local collaboration: The wide-area message bus enables proactive uploading of information from the local dispatch center and automatic matching with the provincial dispatch center, replacing the traditional passive query mode, reducing information transmission delays, and ensuring timely synchronization of power outage and load loss information for important users;

[0051] 4. More coordinated handling solutions: The provincial and local levels respectively call upon appropriate handling methods, and the provincial dispatch center summarizes them to form a unified solution, avoiding isolated handling of the main grid, distribution network and microgrid, improving the efficiency of distributed resource regulation and control, and reducing the impact of faults on grid security and user power supply. Attached Figure Description

[0052] Figure 1 This is a schematic diagram of the method flow of the present invention;

[0053] Figure 2 This is a functional framework diagram of the method of the present invention;

[0054] Figure 3 Flowchart for grid identification;

[0055] Figure 4 Flowchart for grid power failure monitoring;

[0056] Figure 5 Generate a flowchart for the disposal plan;

[0057] Figure 6 This is a schematic diagram of the interface of the master-slave micro-collaboration system. Detailed Implementation

[0058] The technical solution of the present invention will be further described below with reference to the accompanying drawings.

[0059] join Figure 1 A method for handling faults in a master-slave micro-cooperative system includes:

[0060] (1) Dispatch agencies at all levels collect fault perception information within their respective dispatch ranges and generate initial fault events; based on the fault occurrence events and topological distance, the initial fault events of each level of the power grid are integrated and merged to obtain event-based fault events, which include event IDs, and fault impact analysis is performed.

[0061] In one implementation, taking the provincial dispatch center and the regional dispatch center as examples, step (1) specifically includes:

[0062] (11) Layered event perception: The provincial dispatch center and the regional dispatch center respectively collect fault perception information within their respective dispatch scope, including but not limited to: SOE information, protection action signals, PMU data and fault recording data;

[0063] Based on the above data, diagnose the faulty equipment, faulty phase, fault nature (instantaneous / permanent fault), short-circuit current, and fault location to form an initial fault event record.

[0064] (12) Main, Distribution and Micro Network Collaborative Event-Based: Based on the fault occurrence time, topology distance and alarm requirements, the initial fault events of the main network, distribution network and micro network are integrated, including: if there is a chain fault that causes multiple fault devices and is essentially a single fault event, then based on the preset event-based merging rules, the initial fault events at the provincial and local levels are merged into a unified event-based fault event and marked with an event ID.

[0065] The event-based merging rules are used to determine whether the initial fault events of the main network, distribution network, and microgrid (including provincial and municipal level dispatch and collection) originate from the same chain of faults, and then integrate them into a unified event-based fault event. The core objective is to restore a single fault root cause and simplify fault event management.

[0066] In one implementation, the event-based merging rule may include the following conditions:

[0067] 1. Time correlation: The time difference between any two initial fault events is ≤3s (the threshold can be dynamically configured according to the power grid scale).

[0068] 2. Topology correlation: The topological distance between the main grid and the faulty equipment in the distribution network is ≤5km, and the topological distance between the main grid / distribution network and the faulty equipment in the microgrid is ≤2km (the threshold can be dynamically configured according to the power grid scale).

[0069] 3. Causal transmission conditions: The alarm type of the initial event conforms to the logic of "root network → derivative network" (such as main network failure → distribution network tripping, distribution network failure → microgrid disconnection), and the protection action sequence of the derivative event is later than that of the root event.

[0070] 4. Fault root cause uniqueness condition: Through cross-verification of fault waveform data and protection action records, all related initial events originate from the same fault trigger point, and there is no independent fault source;

[0071] 5. Cross-level integration conditions: When the main network events collected by the provincial dispatch and the distribution network / microgrid events collected by the prefecture-level dispatch meet the above conditions 1-4, the fault event merging will be automatically triggered, with the provincial main network fault data as the tracing benchmark.

[0072] (13) Fault impact analysis: Real-time response to fault outage range analysis service requests, restore the normal operation section of the power grid before the fault, and statistically analyze the energized status of equipment and load operation information within the section; based on the fault switch action sequence, the normal operation section is set sequentially to obtain the fault section; by comparing the equipment status of the normal operation section and the fault section, and combining network topology search, statistically analyze the outage equipment, lost load, affected important users and distributed power information within the fault impact range, and output the analysis results.

[0073] (2) Establish a power grid grid model and perform automatic network identification, including: assigning main grid and distribution network equipment to the corresponding grid, merging grids in multi-transformer scenarios, and generating a unique grid identifier; updating the grid division of equipment in real time; and marking the grid ID to which the event-based fault event belongs based on the power grid grid model.

[0074] In one implementation, step (2) specifically includes the following steps:

[0075] (21) Grid model definition: Based on the power grid structure, power supply structure and load characteristics, starting from the low-voltage side of the 220kV main transformer, a topology search is performed along the voltage level descent direction to the boundary equipment of the main grid model, dividing the entire network into several grids; the grid definition follows the following rules:

[0076] Confirm the 220kV and below substations included within the grid;

[0077] Using the low-voltage or medium-voltage side of the transformer within the substation as the grid boundary, all downstream devices below the boundary are automatically identified to the same grid in terms of topology.

[0078] Communication within and between grids is adjusted via the low-voltage side.

[0079] (22) Automatic grid identification (see appendix) Figure 3 ):

[0080] (a) Read the main network device model table and grid information table, and cache the data;

[0081] (b) Using the 220kV main transformer as the boundary device, perform network topology analysis downwards to classify the devices within the boundary into the same grid;

[0082] (c) If another 220kV main transformer is encountered during the topology search, the two grids are merged. The "merge flag" field (unite_flag) of the two grids is set to 1, and the connection area ID is written in the "merge grid ID" field (unite_id). After merging the grids, the grids are written to the grid field of the main network equipment model table.

[0083] (d) If the device grid changes, a message is sent to the distribution network system, which then divides the device into grids. If the device grid does not change, step (b) is returned every 30 seconds for a loop, and step (a) is returned every 10 minutes to restart grid identification.

[0084] (3) Analyze the power outage situation and determine the power outage impact level, and send it to the superior dispatching agency; based on the event ID and grid ID, automatically match the power outage situation and the determined power outage impact level with the local fault information of the superior dispatching agency. If the match is successful, it is merged into a unified alarm event; if the match fails, a separate alarm is issued.

[0085] In one implementation, taking the regional survey center and the provincial survey center as examples, step (3) is used for primary and secondary information coordination, specifically including:

[0086] Regional Dispatch Monitoring Zone I: After diagnosing a fault tripping event, prioritize analyzing the automatic transfer switch action, then interact with the power outage range analysis service to obtain information on the outage equipment and lost load, analyze the impact of the power outage in conjunction with the important user model, rate the event based on the event rating rule base, and actively send the fault event, power outage impact and event rating to the provincial dispatch center through the wide area message bus;

[0087] Provincial Dispatch Monitoring Zone I: Receives information sent from the regional dispatch center, automatically matches it with local fault information, merges alarm events if a match is successful, and issues separate alarms if a match fails. Stores fault events and their impact information using the event number as the association.

[0088] (4) Perform grid power loss statistics and generate a power loss analysis report.

[0089] In one implementation, step (4) specifically includes the following steps:

[0090] (41) Grid power loss ratio analysis and automatic mapping:

[0091] Periodically call the grid identification service and cache grid sections;

[0092] After a failure occurs, a mesh model generation request is received, and the last mesh section before the failure is retrieved from the cache.

[0093] Based on all power-loss devices in the fault event, search the affected grid, extract all device models of the affected grid, and form the affected grid model file;

[0094] The proportion of power-loss devices within the grid is statistically analyzed, and an automatic mapping service is invoked to generate a power supply path map based on the device topology.

[0095] (42) Grid power failure information statistics display: Deploy the statistics display function in the provincial dispatch monitoring zone III, and display the following content based on the provincial and local fault event information integrated by comprehensive intelligent alarm:

[0096] Fault event information: Displays 220kV and above faults identified by provincial surveys and judgments, and 10kV and above faults pushed by local surveys and judgments in reverse chronological order;

[0097] Affected Grid List: This list summarizes all grids containing devices that have lost power, creating a grid record.

[0098] Loss load value: Displays the load loss value for this fault as sent by the regional dispatch analysis;

[0099] Grid device power failure rate: Calculated according to the formula "total number of power failure devices / total number of device records in the grid × 100%". When multiple grids are involved in power failure, the total number of devices in multiple grids is used as the denominator.

[0100] List of power-loss equipment: Displays the substation, equipment name, voltage level, and equipment type (220kV and above are subject to the provincial dispatch results, and below are subject to the regional dispatch results);

[0101] Affecting key users: Displays the names of key users who are affected;

[0102] Mesh power flow map: Automatically generated based on affected mesh devices, with faulty devices located by default, and supports clicking to locate and display the power-out devices.

[0103] (5) The superior dispatching agency generates a unified main, distribution and micro-distribution collaborative handling plan based on the unified alarm events and power failure analysis reports.

[0104] In one implementation, step (5) includes: based on the risk situation of the power grid after the fault, such as equipment exceeding the limit, insufficient zoning margin, power loss of important users, and weak mode, the provincial dispatch center calls on the unit regulation and mode adjustment and other disposal measures, the local dispatch center calls on the load transfer and equipment power restoration and other disposal measures, and the provincial dispatch center summarizes the disposal measures of the provincial and local levels to form a unified main distribution micro-coordinated disposal plan.

[0105] Furthermore, the main-distribution-micro-coordinated fault handling method also includes: displaying at least one of the following information according to the scheduling level: fault perception information, event-based fault events, grid power outage statistics, and main-distribution-micro-coordinated handling plan; the displayed information supports data linkage query between levels.

[0106] In one implementation, the interface display function is deployed in the monitoring zone III system of the provincial and regional surveys, which is divided into four levels: provincial survey, regional survey, county survey, and user. It displays fault perception information, collaborative event results, disposal decision-making schemes, and grid power outage statistics, and supports data linkage query between levels.

[0107] The master-slave micro-coordinated fault handling system includes: an upper-level scheduling subsystem and a lower-level scheduling subsystem, which are communicatively connected; wherein,

[0108] The higher-level scheduling subsystem includes:

[0109] The first layered event perception module is used to collect fault perception information of the power grid within the scope of the upper-level dispatch and generate the first initial fault event.

[0110] The collaborative event-based module is used to integrate and merge the initial fault events of each level of the power grid based on the first initial fault event and the second initial fault event, and the fault occurrence event and topological distance to generate event-based fault events.

[0111] The information coordination module is used to receive information sent by the lower-level scheduling subsystem, and automatically match it with local fault information to merge it into a unified alarm event, or to issue a separate alarm.

[0112] The power loss analysis module is used to perform grid power loss statistics and generate power loss analysis reports.

[0113] The handling plan generation module is used to generate a unified main-distributor-micro-system collaborative handling plan based on the unified alarm event and power failure analysis report.

[0114] The lower-level scheduling subsystem includes:

[0115] The second-level event perception module is used to collect fault perception information of the power grid within the lower-level dispatch range and generate a second initial fault event.

[0116] The fault impact analysis module is used to perform fault impact analysis on the second initial fault event;

[0117] The event rating module is used to analyze power outages, determine the impact level of power outages, and report the results to the higher-level dispatching agency.

[0118] The information proactive uploading module is used to proactively upload the second initial fault event, the fault impact analysis results, and the power outage impact level to the superior scheduling subsystem.

[0119] In one implementation, the system further includes: a grid identification service module, used to establish a power grid model, perform automatic network identification, and serve as the basis for the event rating module to analyze power outages, including: assigning main grid and distribution network equipment to corresponding grids, merging grids in multi-transformer scenarios, and generating a unique grid identifier; updating the grid division of equipment in real time; and labeling the grid ID to which the event-based fault event belongs based on the power grid model.

[0120] In one implementation, the upper-level dispatch subsystem is the provincial dispatch-side system, and the lower-level dispatch subsystem is the regional dispatch-side system. The provincial dispatch-side system is deployed in provincial dispatch monitoring zones I and III, and the regional dispatch-side system is deployed in regional dispatch monitoring zone I. The two systems achieve real-time data interaction through a wide-area message bus. The interface module is deployed in the provincial and regional dispatch monitoring systems in zone III, displaying data at four levels: provincial, regional, county, and user, reflecting information such as fault perception, collaborative event processing, and decision-making. The functions and architectural relationships of each module are as follows: Figure 2 The functional framework diagram of the method of this invention is shown.

[0121] The first layered event perception module serves as the entry point for fault information collection and preliminary diagnosis on the provincial dispatch side, responsible for the accurate capture of fault data from the 220kV and above main grid and associated distribution / microgrids. It receives real-time SOE information, protection device action signals, PMU data, and fault waveform data from the provincial dispatch monitoring zone I. Through integrated intelligent alarm applications, it automatically diagnoses faulty equipment, faulty phases, fault nature (instantaneous / permanent fault), short-circuit current amplitude, and fault location accuracy, forming a structured record of initial fault events in the main grid.

[0122] The collaborative event module is the core module for solving the problem of fragmented fault information in the main distribution / microgrid. It achieves unified integration and normalization of fault events across provincial and municipal levels, as well as between the main and microgrids. It synchronously acquires initial events from the main grid of the provincial dispatching hierarchical event perception module, and initial events from the distribution / microgrid on the regional dispatching side transmitted via the wide-area message bus. Based on three core rules, it determines event correlation—fault occurrence time difference, topological distance (calculated based on grid topology data) less than a preset threshold, and alarm signal type matching—and establishes an event correlation matrix. Multi-source events conforming to the rules are merged to generate a unique event ID, labeled as "Main Distribution / Microgrid Collaborative Event Type." Events not conforming to the rules are stored separately and labeled as "Independent Events." It receives fault impact analysis results in real time and dynamically supplements attribute information such as the power outage range and lost load of the events.

[0123] The information collaboration module is responsible for receiving fault-related information from the regional dispatch center, achieving accurate matching with local faults, alarm event management, and data association and storage. The provincial dispatch center receives data packets actively sent by the regional dispatch monitoring area I in real time via a wide-area message bus, parses and extracts key information such as fault events (including faulty equipment, fault nature, occurrence time, etc.), power outage impacts (list of affected equipment, lost load, affected important users, etc.), and accident rating results. Based on two core conditions—topological distance and fault occurrence time—it automatically matches the information sent by the regional dispatch center with the locally diagnosed fault events in the provincial dispatch monitoring area I. When a match is successful, the regional dispatch information and the local fault event are merged into a unified alarm event, supplementing and improving the event impact information; when a match fails, a separate alarm entry is generated, marked as a "regional dispatch independent fault event" to avoid information omission. Alarm events use a unique event number as an association index. The merged alarm event or the separate alarm event, along with the corresponding fault impact information and accident rating results, are synchronously stored in the provincial dispatch fault event database, ensuring a one-to-one correspondence between events and impact data, supporting subsequent traceability and querying.

[0124] The power outage analysis module is used to accurately assess the power outage status based on grid identification results, connecting the grid identification service module and the power outage information display module. Upon receiving a fault trigger signal, it obtains the pre-fault cached grid operation section and the post-fault real-time grid section from the grid identification service submodule, automatically comparing the differences in parameters such as the equipment's energized status (operating / out of service) and load data between the two sections. Based on a topology search algorithm, starting from the faulty equipment, it traverses the equipment connection relationships within the grid, identifies the topological propagation path of the power-outage equipment, accurately locates the boundary of the power outage area, and classifies and statistically analyzes the number and type of power-outage equipment according to voltage level. When a power outage occurs, it calculates the power outage rate of each affected grid. If the power-outage equipment spans multiple grids, it calculates the power outage rate of each individual grid and the combined power outage rate. It periodically calls the real-time section data from the grid identification service submodule to update the list of power-outage equipment and the power outage rate until the fault is resolved and the grid returns to normal power supply. Based on the equipment topology relationships, it forms power supply path model data and calls the automatic mapping service to generate a power supply path map.

[0125] The power failure rate of the grid devices displayed by the power failure information display module is calculated according to the formula "total number of power failure devices / total number of device records in the grid × 100%". When the power failure device involves multiple grids, the total number of device records in the grid is the total number of devices in the multiple grids.

[0126] The aforementioned disposal plan generation module integrates provincial and local disposal resources with grid power outage information to generate dynamically optimized disposal plans. Based on risks such as equipment exceeding limits after a fault, insufficient zoning margins, power outages of critical users, and weak transmission methods, it calls upon the strategy library to match appropriate disposal methods, and the provincial dispatch center matches main grid-level methods (such as unit regulation, mode adjustment, load transfer, and equipment restoration) to form an initial disposal plan. Based on real-time grid power flow data and power outage update information, it ensures that the grid power outage rate is minimized after the plan is implemented. See also Figure 5 Flowchart for generating the disposal plan.

[0127] The second-layer event perception module, serving as the entry point for fault information collection and preliminary diagnosis on the dispatching side, is responsible for the accurate capture of fault data from 220kV and below, as well as related distribution networks / microgrids. It is used for real-time access to SOE information, protection device action signals, PMU data, and fault waveform data from the dispatching monitoring zone I. Through integrated intelligent alarm applications, it automatically diagnoses faulty equipment, faulty phases, fault nature (instantaneous / permanent fault), short-circuit current amplitude, and fault location accuracy, forming a structured record of initial fault events in the distribution network / microgrid.

[0128] The fault impact analysis module is used to accurately calculate the scope of power outages, load losses, and user impacts caused by distribution network / microgrid faults on the dispatching side. Specifically, it performs the following: upon receiving a fault tripping event, it automatically retrieves the pre-fault operating section from the grid cache to restore the equipment's energized state, load distribution, and microgrid grid connection status; based on the fault switch action sequence and backup automatic transfer action analysis results, it sets the normal section step by step to generate the post-fault grid section; through network topology search, it compares the equipment status differences between the normal and fault sections, compiles a list of outage equipment (including voltage level and equipment type) and load loss, and, combined with an important user model, filters the list of affected important users.

[0129] The event rating module is used to analyze the impact of power outages and determine the level of power outage impact by combining the important user model, and then send the results to the superior dispatching agency.

[0130] The information proactive upload module serves as a crucial channel for uploading information from the regional dispatch center to the provincial dispatch center. It encapsulates information from the initial fault events generated by the regional dispatch center's hierarchical event perception module and the impact results from the power outage range analysis module, according to the unified data format (including field names, data types, and lengths) specified by the provincial dispatch center. This encapsulated data is then proactively uploaded to the provincial dispatch center via a wide-area message bus. The module also receives instructions from the provincial dispatch center's handling plan aggregation module and sends the handling decision plans to the provincial dispatch center for aggregation. (See [link to relevant documentation]). Figure 5 Flowchart for generating the disposal plan.

[0131] The wide-area message bus is used for real-time interaction of information such as fault events, power outage impacts, and handling decision-making schemes between the provincial dispatch system and the regional dispatch system.

[0132] The grid identification service module is used to divide the entire network into several grids based on the power grid structure, power supply structure, and load characteristics. Starting from the low-voltage side of the 220kV main transformer, it performs a topology search along the voltage level decrease direction to the boundary devices of the main grid model. Devices within the boundary belong to the same grid. If another 220kV main transformer is found in the topology search, the "merge flag" field (unite_flag) of the corresponding records of the two grids will be set to 1, and the "merge grid ID" field (unite_id) will be written with the connected area ID. The process of the grid identification service submodule in implementing grid identification is as follows: Figure 3 As shown, this provides the basis for analysis for the event rating module.

[0133] The interface module serves as the visual presentation platform for all core system data, providing differentiated information display services to four levels: provincial survey, regional survey, county survey, and user. For example... Figure 6 As shown, a customized interface is provided based on the permissions and needs of users at different levels. A unified entry point and hierarchical authorization mode are adopted. After a user logs in, the corresponding level of interface content is automatically loaded, and the interface layout can be customized. Data from the hierarchical event perception module is integrated to present fault events in a dual view of event list and topology diagram. The event list displays basic information such as faulty equipment, fault nature, occurrence time, and associated grid ID in reverse chronological order, and supports filtering by voltage level and grid range. A collaborative event dashboard is set up to display merged event-based fault events, with different colors distinguishing event levels and marking event types such as main distribution micro-collaboration and independent dispatch. The disposal plan is presented in the form of solution flowcharts and parameter tables. The flowcharts indicate the disposal steps, responsible parties, execution status (pending execution / in execution / completed), disposal methods, and expected results. Data from the grid power outage analysis module is integrated to present the affected grid name, power outage rate, lost load, and number of affected users in a multi-dimensional way by combining grid list, power flow diagram, and statistical charts. The power flow diagram automatically locates the power outage grid and marks the power outage equipment in gray, supporting drill-down query of "equipment-user". Keyword search and fuzzy search of fault events and grid information are supported.

[0134] Example 1

[0135] Please see Figures 1 to 5 This invention provides a method for handling master-slave micro-cooperative faults, specifically including:

[0136] Step 1: Fault detection and event-based handling

[0137] A permanent fault occurred in a 220kV main grid line of a power grid, which simultaneously caused two downstream 10kV distribution lines to trip.

[0138] Provincial dispatch side: Through SOE information, protection action signals and PMU data, a 220kV line fault (faulty phase A, short circuit current 31kA, fault distance 15km) was diagnosed, forming an initial fault event;

[0139] On the ground control side: by using SOE information and protection action signal data from the distribution network side, a 10kV line trip (a permanent fault) is diagnosed, forming an initial fault event;

[0140] Collaborative event-based: Based on the merging rule of "fault occurrence time difference < 3s, topological distance < 5km", the system determines that two initial events are caused by the same cascading fault, merges them into one event-based fault event, and marks it as "main network 220kV line fault triggers distribution network 10kV line tripping";

[0141] Fault Impact Analysis: Reconstructing the section before the fault (220kV line energized, 10kV line with 20MW load), based on the switch action sequence to set the fault section, it is found that the power outage equipment includes 1 220kV line and 2 10kV lines, with a load loss of 20MW, and 1 important user affected.

[0142] Step 2: Grid Identification and Power Failure Monitoring

[0143] Based on the above fault, the system performs grid identification and power failure monitoring:

[0144] Grid definition: Taking the low-voltage side of the faulty 220kV main transformer as the boundary, perform a downward topology search to assign the lower-level 10kV distribution network equipment to "Grid 1";

[0145] Automatic grid identification: No other 220kV main transformers were encountered during the topology search. The "Merge Identifier" field was set to 0, and the "Merge Grid ID" was set to "000000001".

[0146] Information Collaboration: The local dispatch center analyzes the failure of the automatic transfer switch to operate, and obtains power outage information by combining the power outage range analysis service. The outage information is rated as a "Level 2 event" and actively sent to the provincial dispatch center through the wide area message bus. After receiving the information, the provincial dispatch center successfully matches it with the local 220kV fault and merges it into a unified alarm event.

[0147] Power loss ratio analysis: Before the buffer fault, the "Grid 1" section (including 120 devices) lost power. After the fault, 15 devices lost power, and the power loss rate was 15 / 120×100%=12.5%. The automatic mapping service was called to generate the power supply path map of "Grid 1" and locate the faulty 220kV line.

[0148] Information Display: The fault event (in reverse chronological order) is displayed in the provincial monitoring zone III, along with the affected "Grid 1", load loss of 20MW, power outage rate of 12.5%, important affected names, and power flow diagram of "Grid 1". It also supports clicking to display the location of the 10kV line that lost power.

[0149] Step 3: Generation of Decision-Making Plan

[0150] Based on the above-mentioned failure risks:

[0151] Provincial dispatching side: Utilize unit regulation measures to increase the output of nearby power plants by 10MW, adjust the operation mode of the 220kV power grid, and eliminate equipment exceeding limits;

[0152] On the local dispatch side: load transfer measures were invoked to transfer the power-loss loads within "Grid 1" to nearby 10kV lines to restore power supply to important users;

[0153] Provincial dispatching authorities summarize and formulate a coordinated response plan involving "unit output regulation, power grid mode adjustment, and distribution network load transfer," and distribute it to local dispatching authorities.

[0154] Step 4: Interface Display

[0155] Data is displayed at four levels: provincial, regional, county, and user levels, and information such as fault perception, collaborative event processing, and handling decisions can be obtained as needed.

[0156] Example 2

[0157] This invention also provides a master-slave micro-cooperative fault handling system based on grid identification, specifically including:

[0158] (I) Provincial Dispatch System

[0159] 1. First-level event sensing module

[0160] After the fault occurred at 14:00, the module accessed the SOE information, protection action signals, and PMU data of the provincial dispatch monitoring zone 1 in real time, automatically diagnosed the fault based on the preset fault feature library, and called the topology data of the grid identification service module to mark the grid ID to which the fault belonged as "000000001" (predefined grid 1), forming a structured initial fault event and pushing it to the collaborative event module.

[0161] 2. Collaborative Event Module

[0162] The module synchronously receives the initial fault event from the provincial dispatch center and the initial 10kV distribution network event (tripping of 10kV B / C lines) transmitted by the local dispatch center through the wide area message bus. It initiates merging rule matching: calculates the time difference between the two events, calculates the topological distance based on the topological data of grid 1, and determines the fault type. Once the merging conditions are met, a unique event ID is generated and merged into an event-based fault event, labeled "Fault on 220kV A line of the main grid caused tripping of 10kV B / C lines of the distribution network". After supplementing the grid 1 association identifier, it is synchronized to the information coordination module (provincial dispatch center unit) and the power outage information display module.

[0163] 3. Information Collaboration Module

[0164] This module receives data packets from the regional dispatch center, parses and extracts key information: automatic transfer switch failed to operate; power outage affected equipment included 10kV lines B / C; load loss was 20MW; the affected key user was the People's Hospital; the event rating was Level 2. Based on the event ID and grid ID, it accurately matches the results with the local collaborative event processing, merges them into a unified alarm event, supplements the power outage details from the regional dispatch center, stores it in the provincial dispatch center fault event database using the event ID as an index, and pushes it to the handling plan generation module.

[0165] 4. Power Loss Analysis Module

[0166] Upon receiving the fault trigger signal, the system retrieves the pre-fault cache section of Grid 1 (containing 120 devices, 220kV Line A energized, and 10kV Lines B / C carrying a 20MW load) and the post-fault real-time section (15 devices de-energized) from the grid identification service module. The power outage rate is calculated as 12.5% ​​using the formula "15 / 120×100%". Based on the important user model, the system confirms that the People's Hospital is de-energized, classifying the power outage impact level of Grid 1 as Level II. A power outage analysis report (including a list of de-energized devices, power outage rate, and affected users) is generated and pushed to the response plan generation module and the interface module.

[0167] 5. Decision-making module

[0168] Based on the power outage analysis report, the core risk was identified: a line trip in the 220kV power grid posed a risk of equipment exceeding limits, resulting in power loss for important users within grid 1. The response strategy library was invoked to match appropriate measures: the provincial dispatch center matched unit regulation and grid mode adjustment strategies, while the local dispatch center matched distribution network load transfer strategies. Power flow verification confirmed that increasing the output of the nearby 220kV Ding power plant by 10MW and adjusting the tap changer of the main transformer at the 220kV Jia substation could eliminate the equipment exceeding limits; transferring the load of the 10kV Yi / C lines within grid 1 to the nearby 10kV Wu line could restore power to important users. The local dispatch center's load transfer strategies were summarized and integrated into a collaborative response plan, with the responsible parties and execution deadlines clearly marked. This plan was then distributed to the local dispatch center via the information collaboration module and synchronized with the interface module.

[0169] 6. Interface Module

[0170] The system automatically loads the provincial dispatching interface. The "Collaborative Event Dashboard" highlights secondary events in orange; clicking on these events expands the associated provincial and local initial events and merging criteria. The "Grid Power Outage Monitoring" area displays a power outage rate of 12.5% ​​and a load loss of 20MW for Grid 1, accompanied by an automatically generated power flow diagram for Grid 1 (with red flashing markings for the 220kV A line fault point and gray markings for the 10kV B / C line outage sections). The "Overview of Handling Plans" presents the steps of "Unit Regulation, Mode Adjustment, and Load Transfer" in a flowchart. Parameter tables clearly define the output target of Power Plant D, the location of the main transformer tap, and the load transfer capacity, with real-time updates to the execution status ("Unit Regulation in Progress" at 14:05, "Load Transfer in Progress" at 14:10). After approving the plan through the interface, dispatchers click the "Issue Instruction" button to complete the operation.

[0171] (II) Geological Survey System

[0172] 1. Second-layer event sensing module

[0173] After the fault occurs, the module collects fault recording data and protection action signals of the 10kV B / C line, diagnoses the fault as a permanent fault, marks the grid to which it belongs as 1, and pushes the initial fault event to the ground dispatch side information coordination module.

[0174] 2. Fault Impact Analysis Module

[0175] The module responds to the fault trigger signal, retrieves the pre-fault cache section of grid 1, and sets the fault section based on the 10kV B / C line switch trip sequence. Through topology search, it statistically identifies two 10kV lines as the outage equipment, with a load loss of 20MW. It then calls the important user model to filter out the affected People's Hospital, generates a power outage range analysis report, and pushes it to the information proactive upload module.

[0176] 3. Event Rating Module

[0177] The core indicators extracted from the power outage range analysis report are: load loss of 20MW (15% of the total load of grid 1), 1 affected important user, and no automatic transfer switch activated. Matching the event rating rule base, the event level is determined to be Level 2, and the information is pushed to the proactive information upload module.

[0178] 4. Information proactive upload module

[0179] The information coordination module on the local dispatch side is used to integrate the second initial fault event, the power outage range analysis report, and the secondary event rating results. It encapsulates data packets according to the format specified by the provincial dispatch center and actively sends them to the provincial dispatch monitoring zone I via the wide-area message bus. At 14:00:05, it receives a confirmation signal from the provincial dispatch center. At 14:00:15, it receives the handling plan issued by the provincial dispatch center, extracts the "load transfer" task under the responsibility of the local dispatch center, and forwards it to the local dispatch system.

[0180] 5. Interface Module

[0181] The interface focuses on the details of grid 1: the "Local Fault Details" list displays fault parameters for the 10kV B / C lines, the "Grid Power Loss Details" shows the distribution of power-loss equipment and the location of the People's Hospital, and the "Handling Task List" highlights the "Load Transfer" task, along with the remaining capacity data for the 10kV E line. After viewing the tasks through the interface, dispatchers issue operation instructions to the county dispatch center.

[0182] (III) Operation of Auxiliary Service Module

[0183] 1. Grid Identification Service Module

[0184] Before the fault occurs, the grid 1 section (containing information on 120 devices) is cached periodically. After the fault occurs, it responds to the call from the provincial dispatching side, outputs the section data before the fault, and at the same time performs a new topology analysis with the low-voltage side of the 220kV main transformer A as the boundary to confirm that there are no other 220kV main transformers in grid 1. The "merging identifier" field is set to 0, the "merging grid ID" is set to "000000001", and the grid status is updated to the provincial dispatching side system.

[0185] 2. Automatic map generation service module

[0186] The system receives the interface module's call command, generates a power supply path map based on the topology of the grid 1 devices, locates the fault point of the 220kV line A, marks the power outage section of the 10kV lines B / C, and pushes it to the interface module.

Claims

1. A method for handling faults in master-slave micro-coordination, characterized in that, The method includes: Dispatch agencies at all levels collect fault perception information within their corresponding dispatch areas and generate initial fault events; based on fault occurrence events and topological distance, the initial fault events of each level of the power grid are integrated and merged to obtain event-based fault events, which include event IDs, and fault impact analysis is performed. Establish a power grid mesh model and perform automatic network identification, including: assigning main grid and distribution network equipment to corresponding meshes, merging meshes in multi-transformer scenarios, and generating unique mesh identifiers; updating the mesh division of equipment in real time; and labeling the mesh ID to which the event-based fault event belongs based on the power grid mesh model. Analyze the power outage situation and determine the power outage impact level, and send it to the superior dispatching agency; based on the event ID and grid ID, automatically match the power outage situation and the determined power outage impact level with the local event-based fault events of the superior dispatching agency. If the match is successful, they are merged into a unified alarm event; if the match fails, a separate alarm is issued. Perform grid power loss statistics and generate a power loss analysis report; Based on the unified alarm events and power outage analysis reports, the higher-level dispatching agency generates a unified main, distribution, and micro-distribution collaborative handling plan.

2. The main-supplier-micro-cooperative fault handling method according to claim 1, characterized in that, The method also includes: displaying at least one of the following information according to the scheduling level: fault perception information, event-based fault events, grid power outage statistics, and main-distribution-micro collaborative handling scheme; the displayed information supports data linkage query between levels.

3. The main-supplier-micro-cooperative fault handling method according to claim 1, characterized in that, The fault impact analysis includes: Real-time response to fault outage range analysis service requests, restoration of the normal operation section of the power grid before the fault, and statistics on the energized status of equipment and load operation information within the section; Based on the fault switch action sequence, the normally operating sections are set sequentially to obtain the fault sections. By comparing the equipment status of the normally operating sections and the fault sections, and combining network topology search, the power outage equipment, load loss, affected important users and distributed power information within the fault impact range are statistically analyzed, and the analysis results are output.

4. The main-supplier-micro-cooperative fault handling method according to claim 1, characterized in that, The establishment of the power grid model includes: Based on the power grid structure, power supply structure, and load characteristics, starting from the low-voltage side of the 220kV main transformer, a topology search is performed along the voltage level descent direction to the boundary equipment of the main grid model, dividing the entire network into several grids; the grid definition follows the following rules: (a) Identify the 220kV and below substations included within the grid; (b) Using the low-voltage side or medium-voltage side of the transformer in the substation as the grid boundary, all subordinate devices below the boundary are automatically identified to the same grid in terms of topology; (c) Communication within and between grids is adjusted via the low-pressure side.

5. The main-supplier-micro-cooperative fault handling method according to claim 1, characterized in that, The simultaneous mesh merging in multi-transformer scenarios, generating a unique mesh identifier, includes: Using the 220kV main transformer as the boundary device, a network topology search is performed downwards to assign devices within the boundary to the same grid. If other 220kV main transformers are encountered during the topology search, the two grids are merged and marked. The marking includes: a merge identifier, the grid ID of the relevant interconnected area, and is written into the grid field of the main network device model table.

6. The main-supplier-micro-cooperative fault handling method according to claim 1, characterized in that, The grid division of the real-time update device includes: If the grid of the main grid equipment changes, the distribution network system is notified to divide the grid of the distribution network equipment; if the grid of the main grid equipment does not change, the grid is automatically identified in a cycle to ensure that the grid division matches the grid operation status in real time.

7. The main-supplier-micro-cooperative fault handling method according to claim 1, characterized in that, The process of performing grid power loss statistics and generating a power loss analysis report includes: The grid is automatically identified periodically, and grid sections are cached. After a failure occurs, a mesh model generation request is received, and the last mesh section before the failure is retrieved from the cache. Based on all power-loss devices in the fault event, search the affected grid, extract all device models of the affected grid, and form the affected grid model file; The proportion of power-loss devices within the affected grid is statistically analyzed, and a power supply path map is generated based on the device topology.

8. A master-slave micro-cooperative fault handling system, characterized in that, The system includes: a higher-level scheduling subsystem and a lower-level scheduling subsystem, which are communicatively connected; among them, The higher-level scheduling subsystem includes: The first layered event perception module is used to collect fault perception information of the power grid within the scope of the upper-level dispatch and generate the first initial fault event. The collaborative event-based module is used to integrate and merge the initial fault events of each level of the power grid based on the first initial fault event and the second initial fault event, and the fault occurrence event and topological distance to generate event-based fault events. The information coordination module is used to receive information sent by the lower-level scheduling subsystem and automatically match it with local event-based fault events to merge them into a unified alarm event, or to issue a separate alarm. The power loss analysis module is used to perform grid power loss statistics and generate power loss analysis reports. The handling plan generation module is used to generate a unified main-distributor-micro-system collaborative handling plan based on the unified alarm event and power failure analysis report. The lower-level scheduling subsystem includes: The second-level event perception module is used to collect fault perception information of the power grid within the lower-level dispatch range and generate a second initial fault event. The fault impact analysis module is used to perform fault impact analysis on the second initial fault event; The event rating module is used to analyze power outages, determine the impact level of power outages, and report the results to the higher-level dispatching agency. The information proactive uploading module is used to proactively upload the second initial fault event, the fault impact analysis results, and the power outage impact level to the superior scheduling subsystem.

9. The main-supplier-micro-coordinated fault handling system according to claim 8, characterized in that, The system also includes a grid identification service module, used to establish a power grid model, perform automatic network identification, and serve as the basis for the event rating module to analyze power outages. This includes: assigning main grid and distribution network equipment to their corresponding grids, merging grids in multi-transformer scenarios, and generating unique grid identifiers; updating the grid division of equipment in real time; and labeling the grid ID to which the event-based fault event belongs based on the power grid model.

10. The main-supplier-micro-cooperative fault handling system according to claim 8, characterized in that, The system also includes an interface module for displaying at least one of the following information according to the scheduling hierarchy: fault perception information, event-based fault events, grid power outage statistics, and main-distribution-micro collaborative handling schemes; the displayed information supports data linkage query between levels.

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