A collaborative perception method for operating state of ring network cabinet

Abstract

The application discloses a kind of collaborative perception methods for ring network cabinet operating state, it is related to power distribution automation technical field, for solving single cabinet operating state determination isolated, fault source is difficult to distinguish and the problem of discontinuous after topological change checking;The application generates real-time feeder topology by unified time scale and equipment association through collecting the telemetry, remote signaling, switch action, protection action and terminal communication state of multiple ring network cabinets;When detecting switch position change, protection action or electrical quantity mutation, determine the target ring network cabinet and the expected response of upstream and downstream, interconnection ring network cabinet, form event sequence record data and execute topology checking and timing checking, to identify normal switching, switch refusal or misoperation, upstream power supply anomaly, downstream line fault and terminal anomaly;When topology changes, update power supply path and continue the unfinished event, output fault section, affected ring network cabinet and collaborative perception result, thereby improve the accuracy and continuity of operating state identification and fault location.

Description

Technical Field

[0001] This invention relates to the field of power distribution automation technology, and more specifically, to a collaborative sensing method for the operating status of ring main units. Background Technology

[0002] With the continuous expansion of urban power distribution networks and the increasing demands for power supply reliability, the operation of power distribution lines is becoming increasingly complex. Operations such as line segmentation, load transfer, fault isolation, and power restoration need to be coordinated among multiple power distribution devices. Ring main units (RNBs), as crucial switching equipment in medium-voltage power distribution networks, not only affect the energization of their respective feeder sections but also influence upstream and downstream power supply relationships and the backup power transfer process. When a line experiences switching operations, protection actions, voltage / current surges, or fault isolation, operators need to sequentially verify the telemetry, remote signaling, protection actions, and fault indication information of the target RNB and its upstream and downstream RNBs. This involves determining whether the switches operated correctly, which feeder section the fault is located in, and which RNBs are affected by the power supply disruption. After isolating the faulty section, it is also necessary to operate sectionalizing switches or tie switches to adjust the power supply path and confirm whether power has been restored to the affected area. Therefore, how to continuously and accurately monitor the operating status of multiple RNBs in conjunction with the connection relationships of power distribution lines has become a crucial technical requirement in power distribution automation operation and management.

[0003] However, the telemetry, telesignaling, switch action, and protection action information uploaded by different distribution automation terminals may differ in terms of acquisition time stamp, transmission delay, and equipment identification, making it difficult to sort and correlate events corresponding to the same operational change. Normal switching, switch failure to operate, switch malfunction, upstream power supply abnormality, downstream line fault, and terminal communication abnormality may also produce similar voltage loss, current drop, or telesignaling changes, which are difficult to accurately distinguish based on partial data alone. Especially when the power supply path changes due to the relocation of sectionalizing switches or tie switches, the original upstream and downstream relationships change accordingly. If subsequent events are analyzed based on the feeder topology before the relocation, it is easy to cause errors in judging the fault section, affected ring main units, and power restoration status. Summary of the Invention

[0004] To overcome the aforementioned deficiencies of the prior art, the following solutions are proposed to address the problems of isolated single-cabinet operation status judgment, difficulty in distinguishing fault sources, and discontinuous event verification after topology changes in the aforementioned background technology.

[0005] To achieve the above objectives, the present invention provides the following technical solution:

[0006] A collaborative sensing method for the operating status of ring main units includes the following steps:

[0007] Collect telemetry data, remote signaling data, switch action records, protection action information and power distribution automation terminal communication status of each ring network cabinet; perform unified time stamping on the collected data and associate it according to equipment identification; and generate real-time feeder topology by combining feeder connection relationship, sectional switch status, tie switch status and current power supply mode.

[0008] When a switch change, protection action, or voltage / current change is detected in the target ring main unit, the switch status change, electrical quantity change, and fault indication change that should occur in the target ring main unit and its upstream and downstream power receiving ring main units are determined based on the real-time feeder topology, switch action logic, and protection coordination relationship.

[0009] Based on the time of the event, collect the remote signaling changes, telemetry changes, protection actions, and communication status of the target ring main unit, upstream and downstream power receiving ring main units, and interconnection ring main units to form event sequence record data;

[0010] The event sequence record data is compared with the changes that should occur by performing topology and timing verification to determine normal switching, switch failure or malfunction, abnormal upstream power supply, fault in downstream line or abnormal distribution automation terminal, and to determine the fault section and affected ring network cabinet.

[0011] When a switch change causes a change in the feeder topology, the upstream and downstream relationships and power supply paths between ring main units are updated. Based on the updated real-time feeder topology, events with incomplete state attribution are further verified, and the collaborative perception results of the ring main unit's operating status are output.

[0012] Furthermore, the collected data undergoes unified time-stamping and is associated with device identifiers, including:

[0013] Based on the time synchronization of the distribution automation master station, the system reads the acquisition time stamp and time quality identifier carried by telemetry data, remote signaling data, switch action records, protection action information, and the communication status of the distribution automation terminal. For data that meets the time synchronization requirements, the original acquisition time stamp is retained. For data that does not meet the time synchronization requirements, the time stamp is corrected according to the terminal clock deviation and a time anomaly mark is set.

[0014] Establish equipment correspondence based on ring main unit identification, bay identification, switch equipment identification and distribution automation terminal identification, and associate the collected data after unified time stamping with the corresponding ring main unit and its incoming bay, outgoing bay, segment bay or tie bay.

[0015] The validity status of the collected data is determined based on the data quality identifier, communication status, and the continuity of adjacent collected values ​​at the same measurement point. Abnormal data generated during periods of inconsistent device affiliation, invalid data quality, or communication interruption are set as data that do not participate in the status verification.

[0016] Furthermore, a real-time feeder topology is generated, including:

[0017] Obtain the primary wiring model of the power distribution line, and establish the electrical connection relationship between the power source point, busbar, ring main unit, switchgear and feeder section in the primary wiring model;

[0018] Map the current open / closed state of the sectionalizing switch, tie switch, load switch, and circuit breaker to the primary wiring model, determine the conducting branch based on the switch equipment in the closed position, and determine the disconnected branch based on the switch equipment in the open position.

[0019] Network connectivity analysis is performed along the conductive branches from the power source point. The energized status and power supply direction of the feeders are checked in conjunction with the voltage status and active power direction of each ring main unit. The upstream power supply ring main unit, downstream power receiving ring main unit, interconnection ring main unit and feeder section affiliation of each ring main unit are determined, and the real-time feeder topology is generated.

[0020] Furthermore, determine the switch status changes, electrical quantity changes, and fault indication changes that should occur in the target ring main unit and its upstream and downstream energized ring main units, including:

[0021] When the switch remote signal is detected to change from open to closed or from closed to open, the protection device is activated or outputs, or the change in voltage or current exceeds the corresponding change judgment threshold and continues to reach the specified acquisition cycle, the corresponding ring main unit is identified as the target ring main unit, and the corresponding change trigger time and change type are determined.

[0022] Based on the type of switchgear, switch change direction, protection action type, feeder section and power supply direction of the change in the target ring main unit, call the corresponding switch action logic and protection coordination relationship;

[0023] Determine the upstream power supply ring network cabinet, downstream power receiving ring network cabinet, and interconnection ring network cabinet corresponding to the target ring network cabinet along the real-time feeder topology, and determine the switch position, voltage status, current change direction, power direction, and fault indication status of each ring network cabinet respectively.

[0024] Furthermore, event sequence record data is formed, including:

[0025] Based on the protection action time limit, the switching equipment action time and the data transmission delay of the power distribution automation terminal, the event collection time window is determined with the change trigger time as the benchmark.

[0026] Within the event collection time window, extract the remote signaling change records, telemetry change records, switch action records, protection start records, protection output records, and distribution automation terminal communication status corresponding to the target ring network cabinet, upstream power supply ring network cabinet, downstream power receiving ring network cabinet, and interconnection ring network cabinet.

[0027] The extracted records are sorted according to the event occurrence time after unified time stamp, and each record is marked with the corresponding ring main unit, switch equipment, feeder section, upstream and downstream location and data quality status.

[0028] Records that occur at the same time are kept in parallel according to their source order: protection action record, switch action record, remote signaling change record, and telemetry change record, forming event sequence record data.

[0029] Furthermore, topological verification is performed on the event sequence record data, including:

[0030] Based on the real-time feeder topology, determine the electrical connection path, switch on / off status, and power supply direction between the target ring main unit and the upstream power supply ring main unit, the downstream power receiving ring main unit, and the interconnection ring main unit;

[0031] The actual switch positions, voltage status, current change direction, power direction, and fault indication status of each ring main unit in the event sequence record data are correlated with the expected changes in switch status, electrical quantity, and fault indication.

[0032] When the changed ring main unit, feeder section and change direction are consistent with the electrical connection path and power supply direction, and the state change does not cross the switch equipment in the detachment position, a topology consistency verification result is generated.

[0033] When the state change deviates from the current power supply path, crosses a switch device in a terminating position, or the direction of change does not match the current power supply direction, a topology inconsistency check result is generated.

[0034] Furthermore, the event sequence data is checked for temporal order, including:

[0035] Based on the switch action logic, protection coordination relationship, switch equipment action time and power distribution automation terminal data transmission delay, determine the prescribed order of occurrence and corresponding response time limits between protection start-up, protection output, switch position change, current change, voltage change and fault indication change;

[0036] The actual order and time interval of each change in the event sequence record data are compared with the specified order and response time limit;

[0037] When the switch action record, remote signal change and corresponding electrical quantity change conform to the specified occurrence sequence and are within the corresponding response time limit, it is judged as normal switching;

[0038] When there is a switch action record or protection output record, and the corresponding switch equipment fails to complete the remote signaling change within the action time limit, and the current of the branch does not change according to the switch action requirements, it is determined that the switch fails to operate.

[0039] When a switchgear undergoes a remote signaling change and a corresponding electrical quantity change, but there is no corresponding switch operation source or protection output record, it is determined to be a switch malfunction.

[0040] When the target ring main unit and its downstream power receiving ring main units experience unidirectional voltage loss or load current drop, and the upstream power supply side of the target ring main unit simultaneously experiences voltage abnormality, it is determined to be an upstream power supply abnormality.

[0041] When the upstream power supply side of the target ring main unit remains energized, and the fault current, protection action, or fault indication is concentrated in the downstream feeder section of the target ring main unit, it is determined to be a downstream line fault.

[0042] When the telemetry changes or telesignal changes uploaded by the target ring main unit are not supported by the electrical status of the adjacent ring main units, and are accompanied by invalid data quality, communication interruption or time stamp abnormality, it is determined that the distribution automation terminal is abnormal.

[0043] Further, the faulty section and affected ring main units were identified, including:

[0044] When the judgment result is an abnormal upstream power supply or a fault in the downstream line, the power supply path where the abnormality is located is determined along the real-time feeder topology based on the topology consistency verification result, protection action position, fault indication status and current change direction.

[0045] Tracing along the power supply path to the power supply side, the location in the adjacent feeder section where the fault current or fault indication changes to the absence of fault current or fault indication, or the location of the switching equipment that is in the separation and blocks the abnormal propagation, is determined as the power supply side boundary of the fault section.

[0046] Tracing along the power supply path to the load side, the location where the fault indication stops extending, the location of the switchgear in the detachment, or the end of the feeder is determined as the load-side boundary of the fault section;

[0047] The feeder section between the power supply side boundary and the load side boundary is identified as the fault section, and the ring main unit whose power supply path passes through the fault section and experiences loss of voltage, power outage or change of power source is identified as the affected ring main unit.

[0048] Furthermore, when a switch change causes a change in the feeder topology, the upstream and downstream relationships and power supply paths between ring main units are updated, including:

[0049] The time when the switch change is completed after the timing verification is determined as the topology switching time. The conduction status of the corresponding branch in the wiring model is updated according to the switch opening and closing status after the change.

[0050] The network connectivity analysis is performed again from the power source along the updated conductive branch. The updated feeder energization status and power supply direction are checked in conjunction with the voltage status and active power direction. The upstream and downstream relationships, power supply paths and feeder section affiliations of each ring network unit are then redefined.

[0051] Events that occurred earlier than the topology switchover time are associated with the real-time feeder topology before the changeover, and events that occurred no earlier than the topology switchover time are associated with the real-time feeder topology after the changeover.

[0052] For events whose event collection time window spans the topology switching time and whose state assignment has not yet been completed, topology verification and timing verification are re-executed according to the updated upstream and downstream relationships and power supply paths.

[0053] Furthermore, the collaborative sensing results of the ring main unit's operating status are output, including:

[0054] Summarize the telemetry status, remote signaling status, switch action status, protection action status, power distribution automation terminal communication status, topology verification results, and time sequence verification results corresponding to the target ring network cabinet to determine the operating status type and the reasons for status changes of the target ring network cabinet;

[0055] The operating status type is associated with the corresponding change trigger time, real-time feeder topology, fault section, affected ring network cabinet and event sequence record data, and the topology switching time and data quality status corresponding to the real-time feeder topology used are recorded.

[0056] Based on the status classification records generated according to normal switching, switch failure to operate, switch malfunction, upstream power supply abnormality, downstream line fault or distribution automation terminal abnormality, the output is a collaborative perception result of the ring network cabinet operation status, which includes the target ring network cabinet, operation status type, occurrence time, fault section, affected ring network cabinets and verification basis.

[0057] The technical effects and advantages of the collaborative sensing method for the operating status of ring main units in this invention are as follows:

[0058] This invention unifies the time stamping and equipment identification association of telemetry data, telesignal data, switch action records, protection action information, and distribution automation terminal communication status of multiple ring main units. It generates a real-time feeder topology by combining primary wiring relationships, switch open / closed states, and current power supply methods. This achieves a unified correspondence between operational data from different sources and actual power supply relationships, reducing the impact of data time stamp differences, unclear equipment attribution, and communication anomalies on status judgment. When operational changes occur, based on the topological relationships between the target ring main unit and upstream power supply ring main units, downstream power receiving ring main units, and interconnecting ring main units, it determines the corresponding switch states, electrical quantities, and fault indication changes for each object. Data is recorded in event sequence according to the event occurrence time, enabling continuous association of protection actions, switch changes, and electrical responses during the same operational process.

[0059] Then, by combining topology verification and timing verification, it is determined whether the actual event conforms to the power supply path, switch action logic, and protection coordination relationship, thereby distinguishing normal switching, switch failure or maloperation, upstream power supply abnormality, downstream line fault, and distribution automation terminal abnormality, and determining the fault section and affected ring network cabinet; when the switch change causes the power supply path to change, the upstream and downstream relationship is updated according to the topology switching time, and the events with incomplete status assignment are continued under the updated real-time feeder topology, avoiding the interruption of event judgment during fault isolation, interconnection and power supply transfer, and power restoration, thereby improving the accuracy, continuity, and traceability of ring network cabinet operation status identification, fault location, and impact range determination. Attached Figure Description

[0060] Figure 1 This is a flowchart illustrating a collaborative sensing method for the operating status of a ring main unit according to the present invention.

[0061] Figure 2 This is a schematic diagram of the real-time feeder topology and multi-ring cabinet collaborative sensing relationship of a collaborative sensing method for the operating status of ring main units according to the present invention. Detailed Implementation

[0062] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0063] In order to achieve the above objectives, Figure 1 A flowchart illustrating a collaborative sensing method for the operating status of a ring main unit according to the present invention is provided, which specifically includes the following steps:

[0064] S1. Collect telemetry data, telesignal data, switch action records, protection action information and power distribution automation terminal communication status of each ring network cabinet. Perform unified time stamp processing on the collected data and associate it according to the equipment identifier. Combine the feeder connection relationship, sectional switch status, tie switch status and current power supply mode to generate real-time feeder topology.

[0065] S2. When a switch change, protection action, or voltage / current change is detected in the target ring main unit, the switch status change, electrical quantity change, and fault indication change that should occur in the target ring main unit and its upstream and downstream power receiving ring main units are determined based on the real-time feeder topology, switch action logic, and protection coordination relationship.

[0066] S3. According to the time of event occurrence, collect the remote signaling changes, telemetry changes, protection actions and communication status of the target ring main unit, upstream and downstream power receiving ring main units and interconnection ring main units to form event sequence record data;

[0067] S4. Perform topology and timing checks on the event sequence record data and the changes that should occur to determine normal switching, switch failure or malfunction, upstream power supply abnormality, downstream line fault or distribution automation terminal abnormality, and determine the fault section and affected ring network cabinet.

[0068] S5. When a switch change causes a change in the feeder topology, update the upstream and downstream relationships and power supply paths between ring main units, and continue to verify events with incomplete status attribution based on the updated real-time feeder topology, and output the collaborative perception results of the ring main unit's operating status.

[0069] The collaborative sensing method for the operating status of ring main units described in this embodiment is applied to the operation monitoring and distribution automation management environment of medium-voltage power distribution lines. It is applicable to single-power radial power distribution lines, dual-power ring main lines, or power distribution lines with backup power supply conditions, which consist of multiple ring main units, feeder sections, sectionalizing switches, and tie switches. Each ring main unit is set at the incoming line position, outgoing line position, sectionalizing position, or tie position of the power distribution line to complete power access, line segmentation, load power supply, fault isolation, and power supply path switching.

[0070] Each ring main unit is equipped with one or more incoming line bays, outgoing line bays, segmented bays, or tie bays. Each bay is configured with load switches, circuit breakers, disconnect switches, grounding switches, measuring devices, protection devices, and distribution automation terminals according to its wiring function. The measuring devices, switch auxiliary contacts, and protection devices are connected to the distribution automation terminal. The distribution automation terminal uploads the operating data of each bay and its own communication status to the distribution automation master station for subsequent unified processing.

[0071] The distribution automation master station pre-stores the primary wiring relationships of the distribution lines, the connection relationships between ring main units and feeder sections, the installation locations of each switchgear, and the equipment correspondence between each distribution automation terminal and the ring main unit. The primary wiring relationships are used to represent the electrical connection basis between the power supply point, busbar, ring main unit, switchgear, and feeder section. The real-time on / off status of the switchgear is used to reflect whether each connection branch is currently in a conducting or disconnected state. Based on the operating data uploaded by each ring main unit, the distribution automation master station identifies the current power supply relationship of the distribution lines and determines the upstream power supply ring main unit, downstream power receiving ring main unit, and related objects that can participate in the interconnection and transfer under the current power supply mode.

[0072] like Figure 2 As shown, the distribution automation master station establishes a data connection with the distribution automation terminal corresponding to each ring network cabinet through the communication network, and generates a real-time feeder topology based on the power supply point, switch on / off status, feeder section and connection relationship to determine the upstream power supply ring network cabinet, downstream power receiving ring network cabinet and connection ring network cabinet corresponding to the target ring network cabinet.

[0073] In this embodiment, a single telemetry value or tele-signaling status uploaded by a single ring main unit is not directly used as the result of the operation status determination. Instead, the target ring main unit and its upstream power supply ring main unit, downstream power receiving ring main unit, and interconnecting ring main unit are regarded as interconnected sensing objects. When a switch change, protection action, or voltage / current change occurs in one of the ring main units, the distribution automation master station determines the relevant ring main units and feeder sections that may be involved in this change based on the current power supply relationship of the distribution line, and retrieves the switch status, electrical quantities, protection actions, and communication status of the relevant ring main units during the same operation change process.

[0074] In practice, the data uploaded by each ring main unit is first classified and organized to correspond data from different sources to specific ring main units, bays, and switching equipment. Combined with the primary wiring relationship of the power distribution line and the current switch status, a real-time feeder topology reflecting the current power supply path is formed. After the real-time feeder topology is generated, it continuously monitors whether each ring main unit has experienced switch changes, protection actions, or sudden changes in electrical quantities. When a change in operating status is detected, the corresponding ring main unit is identified as the target ring main unit, and the associated ring main units that need to participate in the status judgment are determined based on its feeder location and the current upstream and downstream relationship.

[0075] Subsequently, the operation records generated by the target ring main unit and related ring main units were extracted based on the change in the operation status. The records were then organized according to their actual occurrence times to ensure that switch operations, protection actions, remote signaling changes, voltage and current changes, and the communication status of the distribution automation terminal could be correlated in the same operation process.

[0076] The distribution automation master station, based on the current feeder connection location and the sequence of changes, collaboratively confirms the operating status of the target ring network cabinet to distinguish between normal switching, switch failure or malfunction, upstream power supply abnormality, downstream line fault, and distribution automation terminal abnormality.

[0077] When the status judgment involves a line fault, the feeder section where the abnormality is located and the ring main unit that may be affected by the power supply are further determined along the current power supply path. When the sectionalizing switch, tie switch, load switch or circuit breaker changes position and causes a change in the power supply path, the upstream and downstream relationship and power supply path of each ring main unit are re-determined according to the switch status after the change, and the operation records generated before and after the change are respectively corresponding to the corresponding feeder topology, so as to avoid interruption of operation status judgment during switching, fault isolation or backup power supply.

[0078] The process includes running data processing and real-time feeder topology generation. Specific implementation details include:

[0079] In this implementation step, the distribution automation master station receives telemetry data, remote signaling data, switch action records, protection action information and distribution automation terminal communication status uploaded by the corresponding distribution automation terminals of each ring network cabinet. Before generating the real-time feeder topology, it performs unified time stamp processing, equipment attribution, data validity judgment and primary wiring model mapping on various types of data in sequence.

[0080] Data acquisition during operation includes:

[0081] Telemetry data is obtained from the measurement interfaces of voltage transformers, current transformers, power measurement units or distribution automation terminals in the ring main unit. Specifically, it includes three-phase voltage, three-phase current, zero-sequence voltage, zero-sequence current, active power, reactive power and active power direction. For ring main units that are not configured with all measurement items, the actual measurement data available is used for subsequent processing. It is not required that each ring main unit upload all telemetry data.

[0082] Remote signaling data includes the open and closed states of load switches, circuit breakers, disconnectors, grounding switches, sectionalizing switches, and tie switches;

[0083] For switchgear using dual-position remote signaling, read the open auxiliary contact and the closed auxiliary contact respectively;

[0084] When neither the split contact nor the merge contact is closed, or when both are closed simultaneously, the corresponding remote signaling is set to an uncertain position state and is not directly used for branch continuity judgment.

[0085] The switch action record includes the source of the operation, the time when the action command was issued, the object to be executed, the target opening and closing position, and the feedback on the completion of the action. The source of the operation can be remote control of the distribution automation master station, on-site manual operation, distribution automation logic control, or protection device output. The protection action information includes protection start, protection output, protection reset, and fault indication information, and records the corresponding protection device, protection type, and action time.

[0086] The communication status of the power distribution automation terminal includes the terminal online status, communication interruption status, message reception status, time synchronization status, and data quality identifier. The communication status is used to determine whether the uploaded data is complete within the corresponding time period, and does not directly interpret the missing telemetry values ​​during the communication interruption as line undervoltage or equipment shutdown.

[0087] Meanwhile, the distribution automation master station uses the master station's time synchronization as a unified time reference. Specifically, the master station and distribution automation terminals can maintain time consistency through satellite time synchronization, network time synchronization, or internal clock synchronization. When uploading various operational data, the terminal acquisition time stamp, data generation time stamp, or action time stamp are carried, along with the time synchronization status and time quality identifier.

[0088] After receiving the running data, the master station first reads the most recent time synchronization record of the corresponding terminal and compares the deviation between the terminal clock and the master station clock.

[0089] For data with valid time quality and clock deviation within the allowable range, the original acquisition time stamp is retained; for data with stable deviation of the terminal clock but the amount of deviation can be determined, the acquisition time stamp is corrected according to the deviation amount, and a time stamp correction mark is set; for data with invalid time quality, terminal clock jump, or where the amount of deviation cannot be determined, the original reception time is retained, and a time anomaly mark is set.

[0090] The allowable range is determined based on the timing accuracy of the distribution automation terminal, the resolution of remote signaling events, the event resolution of the protection device, the switching action time, and the master station communication protocol. Among them, the switching action record and protection action information preferentially use the action timestamp generated internally by the equipment, the telemetry data uses the terminal sampling timestamp, and the master station receiving time is only used to judge the transmission delay and data lateness.

[0091] When the time stamp of continuously uploaded data from the same terminal goes backward, the master station determines whether out-of-order transmission has occurred based on the terminal message sequence number and the collection period. Data whose actual order can be restored by the message sequence number is rearranged according to the collection time stamp; data whose actual order cannot be restored is marked with a time anomaly and restricted from participating in subsequent time sequence verification, but can still be used to determine the current telemetry status.

[0092] Then, the distribution automation master station pre-establishes an equipment identification correspondence table, which includes at least ring main unit identification, bay identification, switch equipment identification, measurement point identification, protection device identification, and distribution automation terminal identification;

[0093] Ring main unit (RNB) identification is used to distinguish each RNB in ​​the distribution line; bay identification is used to distinguish incoming bays, outgoing bays, section bays, and tie bays; switchgear identification is used to identify specific load switches, circuit breakers, or tie switches; measurement point identification is used to identify the bus side or line side to which voltage, current, and power data belong; protection device identification is used to identify the feeder section corresponding to the protection action; terminal identification is used to identify the data upload source.

[0094] For example, the first ring main unit is configured with ring main unit identifier RMU-A, its incoming line bay is configured with bay identifier A01, its outgoing line bay is configured with bay identifier A02, the outgoing line circuit breaker is configured with switch equipment identifier CB-A02, the corresponding three-phase current measurement point is configured with measurement point identifier I-A02, and the terminal responsible for uploading the above data is configured with terminal identifier DTU-A. The master station, according to the equipment identifier correspondence table, uniformly associates the remote signaling change of CB-A02, the current change of I-A02, and the communication status uploaded by DTU-A with the outgoing line bay of the first ring main unit.

[0095] When the terminal identifier carried in the uploaded data is inconsistent with the terminal to which the measurement point belongs, or when the switch equipment identifier is inconsistent with the bay assignment, the data will be set as having an abnormal equipment assignment and will not be used to generate a real-time feeder topology.

[0096] After unifying the time scale and device attribution, the master station determines the validity status of the data based on the data quality identifier, communication status, continuity of measurement points, and consistency of associated data;

[0097] For telemetry data, check whether the value is within the range of the measuring device, and compare the data changes of adjacent acquisition cycles at the same measuring point. If the value exceeds the range, remains fixed for a long time and the terminal reports a measurement abnormality, or there is a sudden change after communication is restored that cannot be connected with the previous and subsequent data, set a telemetry abnormality flag.

[0098] For remote signaling data, check whether the open and closed contacts are mutually exclusive, and confirm whether the remote signaling changes have a corresponding operation source by combining the switch action record. When a dual position conflict occurs, set the switch position to an uncertain state, and use the most recently confirmed valid position to generate a temporary topology. At the same time, set a pending confirmation mark for the branch.

[0099] For terminals with communication interruption, the master station retains the last confirmed switch status before the communication interruption, but does not use the telemetry values ​​during the interruption period for power-on status verification. When communication is restored, the conduction status of the corresponding branch is reconfirmed based on the current telemetry status sent after the restoration.

[0100] After validity processing, a set of current valid operating data corresponding to ring main units, bays, switching equipment, and measurement points is formed.

[0101] The distribution automation master station establishes a primary wiring model based on the distribution line design data, equipment ledger and on-site commissioning information. The primary wiring model includes power supply points, busbars, ring main units, switchgear, feeder sections and load connection points.

[0102] In a single wiring model, power supply points, busbars, and ring main unit bays are set as electrical nodes, cable lines or overhead lines connecting adjacent electrical nodes are set as feeder branches, and load switches, circuit breakers, sectionalizing switches, and tie switches are set at the connection positions of the corresponding branches. Each feeder branch records the starting node, ending node, its feeder, and corresponding switching equipment.

[0103] When power distribution line equipment is added, removed, or the wiring method is changed, the primary wiring model is updated according to the confirmed equipment ledger. The primary wiring model represents the fixed electrical connection basis between equipment, while the real-time feeder topology represents the actual power supply relationship under the current switch opening and closing state.

[0104] Perform switch state mapping and branch connectivity analysis, specifically including:

[0105] The master station maps the confirmed switch open / closed status to the primary wiring model. That is, the branch corresponding to the switch equipment in the closed position is set to the conducting state, the branch corresponding to the switch equipment in the open position is set to the open state, and the branch corresponding to the switch equipment in the uncertain position is set to the pending confirmation state.

[0106] Starting from the currently operational power supply point, network connectivity analysis is performed along the conductive branches. For ring network cabinets that can be connected to the power supply point through continuous conductive branches, they are initially determined to be within the power supply path.

[0107] For ring main units that are isolated by switchbacks and have no other power supply connection path, they are initially identified as non-energized areas;

[0108] For ring main units that can be connected to two power sources respectively, the actual power supply source can be further determined by combining the status of the tie switch and the power direction.

[0109] Network connectivity analysis is performed in the following order: from power source to busbar, from busbar to switchgear, from switchgear to feeder section, and from feeder section to the next ring network cabinet, until the switch, feeder end, or another power source is reached.

[0110] Meanwhile, the main station further verifies the conduction path using voltage state and active power direction, including:

[0111] The voltage status is determined based on the voltage measurement value on the incoming line side or busbar side of the ring main unit. When the voltage measurement value reaches the energized judgment range corresponding to the rated voltage of the distribution line, it is determined to be in a energized state; when it is lower than the de-voltage judgment range and continues to reach the specified acquisition cycle, it is determined to be in a de-voltage state; when it is in between, the previous confirmation state is maintained and a pending confirmation mark is set. The energized judgment range and the de-voltage judgment range are set according to the rated voltage of the distribution line, the accuracy of the measuring device, and the operating procedures.

[0112] The direction of active power is determined according to the positive and negative directions of active power in the corresponding interval. The master station pre-defines the flow from the power source side to the load side as positive.

[0113] For a combined branch, if the upstream power supply ring network cabinet is energized, the downstream power receiving ring network cabinet is energized, and the power direction is from upstream to downstream, then confirm the power supply direction of the branch; if the power direction is opposite to the initial connection direction, check whether the ring network cabinet is powered by the tie power source in reverse and adjust the power supply source.

[0114] When the switch state, voltage presence state, and power direction are consistent, the real-time conduction relationship of the corresponding branch is confirmed; when the three are inconsistent, the branch is set to the topology pending confirmation state, and the switch state, telemetry state, and communication state are retained as the basis for subsequent collaborative verification.

[0115] After completing connectivity analysis and power supply direction verification, the main station determines the upstream power supply ring network cabinet, downstream power receiving ring network cabinet, interconnecting ring network cabinet, and its corresponding feeder section for each ring network cabinet according to the current actual power supply path. Among them, the upstream power supply ring network cabinet is the ring network cabinet that is directly connected to the target ring network cabinet along the current power supply direction and supplies power to it; the downstream power receiving ring network cabinet is the adjacent ring network cabinet that continues to be supplied by the target ring network cabinet along the current power supply direction; the interconnecting ring network cabinet is the ring network cabinet that forms a backup connection or transfer connection with the feeder where the target ring network cabinet is located through an interconnecting switch.

[0116] The real-time feeder topology records at least the connection direction between ring main units, connection switches, switch open / closed status, power supply source, feeder section affiliation, energized status, and topology generation time. This real-time feeder topology serves as the basis for subsequently determining the associated objects of the target ring main unit, verifying cross-ring main unit status changes, and updating the power supply path.

[0117] The implementation details include determining state change triggers and appropriate responses, specifically:

[0118] In this implementation, after the real-time feeder topology is generated, the distribution automation master station continuously receives remote signaling, telemetry, switch action, and protection action information from each ring main unit. It identifies changes in operating status based on the ring main units and their corresponding bays. When a switch change, protection device activation or output is detected, or a change in voltage or current that meets the triggering conditions is detected, the target ring main unit, the triggering time, and the change type corresponding to this operating change are determined. Based on the position of the target ring main unit in the real-time feeder topology, the state response that it and related ring main units should exhibit under normal operating logic is determined.

[0119] For load switches, circuit breakers, sectionalizing switches, and tie switches, the distribution automation master station continuously reads the remote signaling for open and closed positions. When a switch changes from an open state to a closed state, or from a closed state to an open state, and the remote signaling status after the change is maintained for the switch position confirmation time, a switch change is determined to have occurred.

[0120] The switch position confirmation time is determined based on the switch auxiliary contact anti-jitter time, the remote signaling acquisition cycle of the distribution automation terminal, and the remote signaling transmission cycle. This is used to eliminate false changes caused by momentary jitter of the auxiliary contact. For dual-position remote signaling, a change is only determined as valid when the original position contact is deactivated and the target position contact is activated. When the open and closed contacts are activated or deactivated simultaneously, the switch position is set to an uncertain state, and normal switch changes are not triggered by this remote signaling state alone.

[0121] After a valid change occurs, the ring main unit where the switchgear is located is identified as the target ring main unit, the moment when the remote signaling completes the change is identified as the change trigger moment, and the change direction is determined according to the switch type and change direction as load switch opening, load switch closing, circuit breaker opening, circuit breaker closing, section switch change or tie switch change.

[0122] The power distribution automation master station reads the protection start, protection output, and protection reset information uploaded by the ring main unit protection device;

[0123] When the protection device generates protection start information, the ring main unit where the corresponding protection interval is located will be identified as the target ring main unit to be confirmed.

[0124] When the protection device generates further protection output information, the ring main unit is identified as the target ring main unit, and the protection start time is taken as the starting time of the operation change, and the protection output time is taken as the reference time for the switch action response.

[0125] The protection action type is determined based on the function identifier uploaded by the protection device, including overcurrent protection, instantaneous overcurrent protection, zero-sequence current protection, ground fault protection, undervoltage protection, or loss of voltage protection. The protection type is used to determine the monitoring section corresponding to the protection device, the expected action switch, and the coordination relationship between upper and lower level protection.

[0126] When the protection devices of multiple ring main units are activated successively during the same fault process, the target ring main unit directly corresponding to the current operational change is determined by combining the feeder section protected by the protection device, the protection direction, and the real-time feeder topology. The remaining protection-activated ring main units participate in the response determination as associated ring main units.

[0127] For operational changes that are not accompanied by explicit switch changes or protection actions, the distribution automation master station identifies voltage and current surges based on telemetry data.

[0128] It should be noted that voltage change judgment includes voltage drop, voltage recovery, and voltage loss. Voltage drop refers to the voltage on the incoming side, bus side, or outgoing side of the ring main unit decreasing relative to the stable operating range before the change, with the decrease exceeding the corresponding voltage change judgment threshold and continuing for a specified acquisition period. Voltage recovery refers to the measurement point that was originally in a state of no voltage or low voltage returning to the energized judgment range and maintaining it for a specified acquisition period. Voltage loss refers to the voltage at the measurement point dropping to the voltage loss judgment range and continuing for a specified voltage loss confirmation time.

[0129] Current change determination includes current surge, current drop, and current disappearance. Current surge is used to reflect the increase in branch current caused by load input, short circuit fault, or power supply path switching; current drop is used to reflect load removal, upstream power failure, or switch tripping; current disappearance is used to reflect the corresponding branch stop supplying power. The current change determination threshold is determined based on the line rated current, the accuracy of the measuring device, the normal load fluctuation range, and the protection setting range.

[0130] To prevent frequent triggering caused by normal load fluctuations, the master station uses the stable operating state over several consecutive acquisition cycles before the change as a comparison benchmark, and requires that voltage or current changes continuously meet the specified acquisition cycle. The specified acquisition cycle is set according to the telemetry refresh cycle and the operating characteristics of the power distribution line.

[0131] When multiple measurement points of the same ring main unit change simultaneously, the measurement points on the incoming line side, bus side, or fault interval that can reflect the change in power supply status are selected as the trigger measurement points, and the ring main unit is determined as the target ring main unit. If multiple adjacent ring main units experience voltage or current changes in the same direction at similar times, the ring main unit involved first in the power supply direction is determined as the target ring main unit based on the real-time feeder topology, and the remaining ring main units are regarded as upstream and downstream related objects.

[0132] Once the target ring main unit is determined, the distribution automation master station reads the type of switching equipment that has changed within the target ring main unit, the direction of the change, the type of protection action, the interval where the measurement point is located, the feeder section affiliation, and the current power supply direction. It then determines whether the change is classified as a normal operation, a protection action, or an electrical state change. Specific details include:

[0133] Normal operation includes planned tripping, planned closing, sectionalizing switch operation, tie switch operation, and load transfer operation; protection action includes tripping after protection is activated and protection is activated but has not yet activated; electrical status change includes voltage loss caused by upstream voltage anomaly, current change caused by downstream load or fault, and voltage recovery and power direction change caused by backup power supply activation.

[0134] Based on the real-time feeder topology, determine the upstream power supply ring network cabinet and the downstream power receiving ring network cabinet that are directly connected to the target ring network cabinet along the current power supply direction; for the target ring network cabinet with a connecting branch, also determine the connecting ring network cabinet that has a backup power supply connection with it; the determination of associated objects is based on the current conducting branch, and ring network cabinets that are on the other side of the switch and have not participated in this power transfer are not considered as upstream and downstream objects on the current power supply path.

[0135] The switching action logic is determined, including:

[0136] The distribution automation master station pre-stores the switching action logic corresponding to different switching equipment and different operating modes. The switching action logic includes at least the operation source, target switch position, corresponding branch conduction status, electrical quantity change direction and adjacent ring network cabinet power supply status change.

[0137] When the outgoing switch of the target ring main unit changes from the closed position to the open position, there should be a response including the target switch changing to the open position, the corresponding outgoing current decreasing or disappearing, and the voltage of the ring main unit downstream of the switch and without other power sources decreasing or losing voltage; the voltage on the upstream side of the target ring main unit should remain within the normal energized range.

[0138] When the outgoing switch of the target ring main unit changes from open to closed, there should be a response including the target switch changing to closed, the corresponding branch changing from disconnected to conductive, the outgoing current changing from no current or low value to an operating value adapted to the downstream load, and the downstream energized ring main unit being restored to power.

[0139] When the sectionalizing switch changes from the open position to the closed position, the required response should be determined based on the energized status of both busbars. If one side is energized while the other side is de-energized, the de-energized side should be restored to voltage after closing, and the power direction should be from the energized side to the original de-energized side. If both sides are energized, the operation should be carried out under the condition of synchronizing or preventing asynchronous closing. If the operating conditions are not met, parallel operation of both sides should not be considered as a normal response.

[0140] When the tie switch changes from open to closed, the transfer response should be determined based on whether the original power supply path has been isolated. If the fault section has been isolated, after the tie switch is closed, the receiving ring network cabinet should restore voltage, and the direction of its incoming active power should be adjusted from the standby feeder to the receiving area. The original power supply side disconnect switch should remain open.

[0141] The determination of the protection and coordination relationship includes the following specific contents:

[0142] The protection coordination relationship is established based on the location of the protection device, the protection range, the action type, the setting time limit, and the configuration of the upper and lower level protection. In the event of a fault in the downstream feeder section of the target ring network cabinet, the corresponding protection device of the target ring network cabinet should be activated first, and after reaching the output condition, it should output a trip signal to the corresponding circuit breaker or load switch; the corresponding switch should switch to the open position within the specified action time, and the fault branch current should decrease or disappear accordingly.

[0143] When the downstream protection and switch are operating correctly, the ring main unit upstream of the target ring main unit should remain energized and should not trip over the next level; the ring main unit downstream of the target ring main unit and within the fault isolation range should experience a loss of voltage or a drop in current; the fault indication device should generate a corresponding indication in the feeder section through which the fault current flows and stop extending beyond the fault isolation boundary.

[0144] When the target ring main unit protection is activated but the corresponding switch has not yet tripped, the response should retain the action requirements between protection activation, protection output, switch tripping, and fault current disappearance, so as to allow subsequent judgment on whether the protection and switch actions are complete based on the actual event.

[0145] For voltage loss caused by upstream power supply anomalies, the target ring main unit itself should not have an active tripping operation source. Its upstream power supply ring main unit and downstream power receiving ring main unit should have a voltage drop in the same direction along the current power supply path. The downstream load current of the target ring main unit should decrease with the power supply interruption. For abnormalities in the downstream line of the target ring main unit, the upstream side of the target ring main unit should remain energized. Abnormal current, protection action or fault indication should be concentrated in the downstream feeder section of the target ring main unit.

[0146] After completing the switching action logic and protection coordination relationship invocation, the distribution automation master station determines the expected operational changes for the target ring main unit, upstream power supply ring main unit, downstream power receiving ring main unit, and interconnection ring main unit. Following this, the distribution automation master station associates the corresponding switch positions, voltage status, current change direction, active power direction, protection action status, and fault indication status with the target ring main unit, upstream power supply ring main unit, downstream power receiving ring main unit, and interconnection ring main unit, respectively, forming expected response records. Each expected response record includes a change trigger identifier, corresponding ring main unit, bay, switching equipment or measurement point, expected status, change direction, response start condition, and response time limit, serving as a comparison benchmark for subsequent event extraction, topology verification, and timing verification.

[0147] Each item should have a response, and the corresponding ring main unit, bay, switching equipment or measurement point, direction of change, and applicable response time limit should be recorded.

[0148] The specific implementation details of event sequence record data formation include:

[0149] After determining the target ring main unit, the trigger time of the change, the type of change, and the responses that the target ring main unit and associated ring main units should take, the distribution automation master station takes the current change in operating status as the processing object, extracts records that are time-related and topologically related to the current change from the continuously received operating data, and organizes them into event sequence record data according to a unified time scale. The event sequence record data is used to reflect the occurrence of switch operation, protection action, remote signaling change, electrical quantity change, and distribution automation terminal communication status in the same operating change process, providing a data foundation for subsequent topology verification, timing verification, and operating status attribution.

[0150] Determining the event aggregation time window includes:

[0151] The distribution automation master station uses the change trigger time as a benchmark, sets an event tracing period forward and a response confirmation period backward, and the event tracing period and response confirmation period together constitute the event collection time window;

[0152] The event tracing period is used to extract the source of switch operations, protection activation, telemetry change trends, and communication status changes that may have occurred before the change was triggered. For example, when a switch remote signal change is used as a trigger condition, the switch action command or protection output usually occurs earlier than the remote signal change, so it is necessary to trace back the corresponding operation record. When a voltage drop is used as a trigger condition, it is necessary to extract the protection activation, fault current change, and upstream power supply ring network cabinet voltage change to determine whether the voltage drop belongs to the same operational change process.

[0153] The response confirmation period is used to extract information that should continue to occur after a change is triggered, such as the completion of switch actions, remote signaling changes, voltage and current responses, fault indication changes, and the communication status of distribution automation terminals. For example, after a protection outage occurs, it is necessary to continue to obtain information within the response confirmation period on whether the corresponding switch has completed tripping, whether the fault branch current has decreased, and whether the downstream power receiving ring network cabinet has experienced a loss of voltage.

[0154] The event tracing period is determined based on the setting time limit from protection activation to protection output, the time from switch operation command to mechanism action start, and the time when telemetry changes may precede remote signaling changes; the response confirmation period is determined based on the allowable time from protection output to switch action completion, the time required for electrical quantities to stabilize after switch action, the telemetry refresh cycle of distribution automation terminal, the remote signaling transmission cycle, and communication transmission delay.

[0155] Different event collection time windows can be configured for different change types. The time window corresponding to normal switching operation mainly covers operation instructions, switching actions, remote signaling changes and electrical quantity changes; the time window corresponding to protection action should also cover protection start-up, protection output, fault indication and fault current changes; the time window corresponding to undervoltage or current change should appropriately increase the forward tracing range to extract electrical quantity changes in adjacent ring main units that may occur before the target ring main unit.

[0156] The start and end times of the event collection time window are recorded together with the change trigger time. If there are still responses that should have occurred but have not yet occurred by the end of the response confirmation period, the entire event record is not directly extended. Instead, the corresponding response missing marker is retained for subsequent timing verification.

[0157] Then, the distribution automation master station determines the equipment objects involved in this event extraction based on the real-time feeder topology and the aforementioned expected response content. The equipment objects include at least the target ring main unit, the upstream power supply ring main unit directly connected to the target ring main unit, the downstream power receiving ring main unit, and the connecting ring main unit with a transfer or connection relationship.

[0158] When the target ring main unit is in the feeder branch position, the adjacent branch ring main units that have the same upstream power supply source as the target feeder section can also be used as reference objects to record whether they maintain normal power supply. For ring main units that are isolated by the switch and do not participate in the current operation change, they are not included in the scope of this event extraction, thereby avoiding mixing irrelevant events of other independent feeder sections into the event sequence record data.

[0159] The scope of event extraction is adjusted according to the type of change. When a switch is opened or closed, the focus is on extracting the operation records of the ring main units on both sides of the target switch; when a protection device is activated, upstream and downstream records are extracted along the corresponding feeder section of the protection device and the current power supply direction; when a power supply is switched, the relevant ring main unit records in the original power supply path and the backup power supply path are extracted simultaneously.

[0160] Within the event collection time window and event extraction range, the distribution automation master station extracts the following operation records:

[0161] Remote signaling change records include changes in open and closed contacts of load switches, circuit breakers, sectionalizing switches, and tie switches, as well as uncertain position states.

[0162] Telemetry change records include voltage sags, voltage recovery, loss of voltage, current surges, current drops, current disappearance, and changes in the direction of active power;

[0163] The switch action record includes the source of the action command, the time of action initiation, the target switch position, the execution feedback, and the action completion status;

[0164] Protection action records include protection activation, protection exit, protection reset, protection type, and protected object;

[0165] Fault indication records include the activation and reset of the fault indication device and the corresponding feeder section;

[0166] The communication status of distribution automation terminals includes terminal online status, terminal offline status, communication recovery status, time synchronization anomaly, and data quality changes.

[0167] For telemetry data, each periodic sample value is not treated as an independent event. Instead, based on the aforementioned change triggering conditions, changes with clear state meanings in continuous sample data are converted into telemetry change records. Each telemetry change record includes at least the change start time, the confirmation time when the change judgment conditions are met, the state before the change, the state after the change, and the direction of the change. The original sample values ​​are still retained in the corresponding records to support subsequent verification.

[0168] The event occurrence time of all types of records is determined by the aforementioned unified time stamp processing. Among them, remote signaling change corresponds to the time of auxiliary contact change, switch action and protection action correspond to the time of device action, and terminal communication status corresponds to the time when the master station confirms that the terminal is offline or restored.

[0169] Because the data structures uploaded by telemetry, telesignaling, protection devices, and distribution automation terminals are different, the distribution automation master station provides a unified description for all types of extracted records.

[0170] Each standardized event record includes at least the event identifier, event occurrence time, master station reception time, event type, data source, ring main unit identifier, bay identifier, switchgear or measurement point identifier, feeder section identifier, upstream and downstream location, state before change, state after change, and data quality status. The event occurrence time represents the actual timestamp corresponding to the equipment acquisition or device action, and the master station reception time represents the time the record arrives at the distribution automation master station. Event sequencing is primarily based on the event occurrence time after standardized timestamp processing, and does not substitute the order of communication transmission for the actual occurrence order.

[0171] Event types are marked according to remote signaling change, telemetry change, switch action, protection start, protection output, protection reset, fault indication and communication status. The upstream and downstream positions are determined according to the real-time feeder topology corresponding to the time of change triggering, and are marked as target ring network cabinet, upstream power supply ring network cabinet, downstream power receiving ring network cabinet or interconnection ring network cabinet respectively.

[0172] Data quality status includes valid, timestamp corrected, time anomaly, device attribution anomaly, invalid data quality, communication interruption, and data lateness. Data not participating in status verification is still retained in the event sequence record data, but a flag indicating it is not participating in verification is set to prevent the inability to explain the reason for event missing if the data is directly deleted.

[0173] After standardization is completed, the distribution automation master station sorts all event records within the event collection time window in ascending order according to the event occurrence time after the unified time scale.

[0174] When the order in which records arrive at the master station is inconsistent with the time of the event, they are reordered according to the time of the event. For example, if the protection device record arrives at the master station later than the remote signaling record due to communication delay, but its action timestamp is earlier than the remote signaling change time, then the protection action record will still be arranged before the remote signaling change record in the event sequence record data.

[0175] Event sorting directly adopts the aforementioned unified time-scaled processing results, and the original time scale, corrected time scale, and time quality status are retained along with the corresponding event records;

[0176] Events marked with time anomalies are not included in the main event sequence with a definite chronological relationship. Instead, they are associated with the corresponding event aggregation time window as time-pending events. They will only be used as auxiliary verification criteria when their equipment location, status change content, and responses from adjacent ring network cabinets can support each other.

[0177] When late data arrives after the event collection time window has closed, if the event occurrence time carried by the data is within the time window and the data quality is valid, it will be added to the corresponding position, and the version identifier of the event sequence record data will be updated; if the event occurrence time of the late data exceeds the time window, it will be processed as pending data of the adjacent running change process.

[0178] When two or more event records have the same event occurrence time, or their time standard difference is less than the time resolution capability of the corresponding device, their order is not determined manually according to the main station's receiving order, but rather they are marked as parallel events that occurred at the same time.

[0179] Parallel events are retained according to their data sources as protection action records, switch action records, remote signaling change records, and telemetry change records. The order of sources is only used for the display and organization of event data and does not indicate a definite sequential relationship between parallel events.

[0180] For example, when protection output records and switch action records have the same millisecond timescale, they are set as parallel records at the same event time; when the three-phase currents decrease simultaneously, the telemetry change records corresponding to the three measurement points are retained and associated with the same current change event group; when the opening of the trip contact and the closing of the close contact are within the same time resolution range, the two telemetry changes are represented as one effective trip change.

[0181] By preserving parallel relationships, we can avoid incorrectly constructing the order of events due to differences in device timescale precision, thus providing an objective data basis for subsequent time sequence verification based on response time limits.

[0182] When the same device repeatedly uploads the same event through different communication channels, duplicate records are identified based on device identifier, event type, event occurrence time, and status change content. For duplicate records with identical content, one master record is retained, and other data sources are recorded. For records with similar event times but inconsistent changes, data conflict flags are set for each record.

[0183] Switch action records, remote signaling change records, and corresponding telemetry change records are not deleted as duplicate data. Instead, they are associated with the same switchgear, feeder section, and time proximity. Protection start-up, protection output, and fault indication records are associated with the protection device and protection section.

[0184] During an operational change, there may be multiple protection activations, multiple switch changes, or multiple electrical quantity changes. All of the above records retain their respective event identifiers and are associated with the sequential record data of this event through the same change trigger identifier.

[0185] During the formation of event sequence record data, the distribution automation master station sets data quality tags based on data quality, time quality, communication status, and equipment affiliation.

[0186] When device data corresponding to a required response cannot be obtained due to communication interruption, a communication missing flag is set; when a device is online but no corresponding record appears within the event collection time window, a response not appearing flag is set; when a record has appeared but the timestamp is abnormal, a response time pending confirmation flag is set; when the same device uploads conflicting states, a state conflict flag is set.

[0187] It should be noted that communication loss and no response have different meanings. Communication loss means that the system cannot confirm whether the device has generated a corresponding response, while no response means that no corresponding change was detected when the data is valid and communication is normal. The two are handled separately in subsequent timing verification and terminal anomaly determination.

[0188] After event extraction, standardization, time sorting, parallel processing, duplicate identification, and data quality marking, event sequence record data corresponding to the current change in operational status is formed.

[0189] The event sequence record data includes the change trigger identifier, change trigger time, event aggregation time window, target ring network cabinet, associated ring network cabinet, real-time feeder topology identifier used, and multiple event records arranged by the event occurrence time;

[0190] Each event record retains the corresponding ring main unit, feeder section, equipment object, event type, event occurrence time, change content, and data quality status. Among them, the event sequence record data is only used to objectively reflect the actual response of the relevant ring main unit during this operation change process, and does not directly determine normal switching, switch failure, line fault, or terminal abnormality in this step.

[0191] The distribution automation master station will submit the event sequence record data, along with the switch status changes, electrical quantity changes, and fault indication changes that should occur in the aforementioned target ring network cabinet and associated ring network cabinets, to the subsequent verification process. Subsequently, it can determine whether each actual change conforms to the current electrical connection path and power supply direction based on the real-time feeder topology, and determine whether the occurrence sequence of each event conforms to expectations based on the switch action logic, protection coordination relationship, and response time limit.

[0192] The implementation includes topology verification, timing verification, status determination, and fault impact assessment.

[0193] After the event sequence record data is generated, the distribution automation master station calls the real-time feeder topology corresponding to the change trigger time and compares the event sequence record data with the switch status changes, electrical quantity changes, and fault indication changes that should occur in the aforementioned target ring main unit and associated ring main units. First, the topology is checked based on the location of the event, the feeder connection path, and the power supply direction. Then, the timing is checked based on the order of occurrence of protection actions, switch actions, and electrical quantity responses to determine the operating status type of the target ring main unit. When the operating status involves upstream power supply abnormality or downstream line fault, the fault section and affected ring main units are determined by continuing to follow the real-time feeder topology.

[0194] Specifically, the distribution automation master station reads the real-time feeder topology identifier recorded in the event sequence record data, and retrieves the upstream and downstream relationship of the ring network cabinet, the on / off status of the switch, the feeder section ownership and the power supply direction corresponding to the change trigger time based on the identifier;

[0195] Each event in the event sequence record data is mapped to the corresponding position in the real-time feeder topology according to the ring main unit identifier, interval identifier, switch equipment identifier, or measurement point identifier, and it is determined whether the event belongs to the target ring main unit, upstream power supply ring main unit, downstream power receiving ring main unit, or interconnection ring main unit.

[0196] The verification criteria include the required switch positions, required voltage states, required current change directions, required power directions, required protection actions, and required fault indication states determined in the aforementioned steps. The verification criteria correspond to the type of change in this case, and response requirements under other operating modes are not used for the judgment of the current event.

[0197] For example, when the outgoing switch of the target ring main unit is opened, there should be a response including the target switch turning to the open position, the corresponding branch current decreasing, and the downstream receiving ring main unit not powered by other power sources losing voltage; when the tie switch is closed, there should be a response including the tie branch being turned on, the voltage of the receiving ring main unit being restored, and the active power direction changing.

[0198] Topology verification is used to determine whether the actual state changes recorded in the event sequence data conform to the current electrical connection path, switch on / off status, and power supply direction, including:

[0199] Starting from the target ring main unit, the distribution automation master station checks the ring main units and feeder sections whose status has changed along the upstream power supply direction, downstream power receiving direction, and interconnection direction. For each actual status change, it determines whether there is a continuous conductive path between it and the target ring main unit, and whether there are any switchgear in the detached position in the continuous conductive path.

[0200] When the switch position change, voltage status, current change direction, power direction, and fault indication status of the target ring main unit are all consistent with the corresponding response, and the change of the associated ring main unit extends along the current power supply path without crossing the switch equipment in the detached position, a topology consistency verification result is generated.

[0201] For example, when a fault occurs in the downstream feeder of the target ring main unit, the fault current and fault indication should be located within the downstream conduction path of the target ring main unit; the ring main unit upstream of the target ring main unit should remain energized, and the fault indication should not extend beyond the already tripped disconnector to the load side.

[0202] When the actual state change occurs outside the current power supply path, crosses a switchgear in a separate position, the corresponding ring main unit and the target ring main unit are not electrically connected, or the direction of active power change does not match the current power supply direction, a topology inconsistency check result is generated, and the corresponding inconsistency location, switchgear and state change content are recorded.

[0203] For branches where there are contradictions between switch remote signaling, voltage status, and power direction, topology consistency is not determined directly based on a single data point, but rather by considering the data quality status of the branch. If the remote signaling data quality is invalid, the actual conduction relationship reflected by the electrical quantity is not negated based on the remote signaling status. If the telemetry data is during a communication interruption, the switch position indicated by the valid remote signaling is not negated based on the missing voltage or power data.

[0204] Determining the timing verification benchmark includes:

[0205] Timing verification is used to determine whether the sequence and time interval of various state changes conform to the switching action logic and protection coordination relationship;

[0206] Based on the type of change, the distribution automation master station reads the corresponding protection device's action time limit, protection output time limit, switch equipment's rated action time, auxiliary contact feedback time, distribution automation terminal's data acquisition cycle, and data upload delay, and determines the prescribed order of occurrence and response time limit between various events accordingly.

[0207] The prescribed sequence of events for normal remote-controlled tripping includes the formation of the operation command, execution of the switch mechanism, change of the remote signal from the closed position to the open position, and a decrease in branch current. The prescribed sequence of events for protection tripping includes protection activation, protection output, switch tripping, remote signal change, and a decrease in fault current. The prescribed sequence of events for interconnection and power transfer includes isolation of the original fault section, closing of the interconnection switch, restoration of voltage in the receiving area, and change of power direction.

[0208] The response time limit is not arbitrarily uniform, but is determined based on the protection setting sheet, the technical parameters of the switchgear, the terminal acquisition configuration, and the communication operation parameters. Different models of switchgear and different protection types can be configured with different response time limits.

[0209] The power distribution automation master station records the event occurrence time in the data according to the event sequence, compares the actual event sequence with the prescribed occurrence sequence, and calculates whether the time interval between adjacent responses is within the corresponding response time limit;

[0210] The timing verification is based on the event occurrence time after unified time stamp processing, and the main station reception time is only used to identify data delays and communication transmission anomalies.

[0211] When late data carries a valid action timestamp, restore its actual position in the event sequence record data according to the action timestamp;

[0212] For events with the same time scale or a time scale difference less than the device's time resolution, they are treated as parallel events. Their order is not determined artificially. As long as the parallel events are all within the allowable response time limit and do not violate the necessary sequence conditions between protection actions and switching actions, the corresponding timing requirements can be considered met.

[0213] When the expected response occurs within the specified response time limit, it is recorded as timing conformity; when the expected response occurs after the specified response time limit, it is recorded as response delay; when no corresponding response occurs after the event collection time window ends, it is recorded as response missing; when the actual occurrence order is the opposite of the specified occurrence order, it is recorded as timing inconsistency.

[0214] For events marked with time anomalies, the determination of whether a switch fails to operate or operates erroneously is not made solely based on this. Instead, the switch position, changes in electrical quantities, and the status of adjacent ring main units are used for auxiliary confirmation.

[0215] The normal switching status determination includes the following:

[0216] When the event sequence record data contains records of manual operation, master station remote control or automatic control corresponding to the target switch, the target switch completes remote signaling change according to the operation requirements, the corresponding branch current and voltage change according to the switch opening and closing state, and the response of the upstream and downstream power receiving ring network cabinets conforms to the current real-time feeder topology, it is judged as normal switching.

[0217] For the operation of sectionalizing switches or tie switches, it should also be confirmed that the energized area and power direction after the operation conform to the predetermined power supply mode. If the switch is closed but the voltage on the receiving side is not restored, or the power direction does not conform to the predetermined transfer direction, it is not considered a complete normal switching process.

[0218] The process of determining whether a switch fails to operate or malfunctions includes the following:

[0219] When there is a valid switch action record or protection output record, but the corresponding switch equipment fails to complete the remote signaling change within the specified action time limit, and the current of the branch does not change according to the opening or closing requirements, it is determined that the switch fails to operate.

[0220] If the auxiliary contact of the switch has not changed position, but the current in the branch has disappeared or recovered, and the voltage status of the adjacent ring main unit supports the actual operation of the switch, then this situation should be treated as an abnormal remote signaling feedback, and the switch failure to operate should not be determined solely based on the absence of remote signaling change.

[0221] When a switchgear experiences a remote signaling change, accompanied by a change in the conduction status or electrical quantity of the corresponding branch, but there is no corresponding record of manual operation, master station remote control, automatic control, or protection output, it is determined to be a switch malfunction.

[0222] If only a remote signaling change occurs, but the voltage, current and adjacent ring main unit status on both sides of the target switch do not change accordingly, and the remote signaling data is accompanied by abnormal data quality, it will not be judged as a switch malfunction, but will be transferred to the distribution automation terminal for abnormal judgment.

[0223] The process of determining upstream power supply anomalies includes the following:

[0224] When the target ring main unit and its downstream powered ring main units experience a voltage drop, loss of voltage, or load current drop along the current power supply path, and there is no record of active switch tripping in the target ring main unit, and a voltage abnormality occurs synchronously on the upstream power supply side of the target ring main unit, it is determined to be an upstream power supply abnormality.

[0225] During the judgment process, it should also be checked whether the connecting power supply has been put into operation. If the original upstream power supply of the target ring main unit is lost, but the connecting branch has been restored to power supply, the original power supply path will be identified as an abnormal upstream power supply path, and the target ring main unit will be recorded as having a changed power supply source, instead of continuing to be judged as the currently lost-voltage ring main unit.

[0226] The process of determining faults in downstream lines includes the following:

[0227] When the upstream power supply side of the target ring main unit remains energized, and a fault current, protection activation, protection output, or fault indication occurs in the downstream feeder section of the target ring main unit, and the abnormal changes are concentrated in the downstream conduction path of the target ring main unit, it is determined to be a downstream line fault.

[0228] If the corresponding switch after the protection output of the target ring main unit is correctly tripped, the fault current will disappear. The upstream power supply ring main unit will remain energized while the downstream power receiving ring main unit in the fault section will lose voltage, further confirming the downstream line fault and the establishment of the protection isolation process.

[0229] When the fault indication is inconsistent with the direction of current change, or when the fault indication crosses the switchgear in the open position, the inconsistency will be retained as evidence of data abnormality, and the fault location will not be determined directly based on a single fault indication.

[0230] The process of determining anomalies in power distribution automation terminals includes the following:

[0231] When the telemetry changes or tele-signaling changes uploaded by the target ring main unit are not supported by the electrical status of the adjacent ring main units, and the corresponding data is accompanied by invalid data quality, communication interruption, abnormal time stamp, dual-position tele-signaling conflict, or discontinuous data at the same measurement point, it is determined that the distribution automation terminal is abnormal.

[0232] For example, if the remote signaling display of the target ring network cabinet shows that the outgoing switch has been opened, but the branch current remains unchanged, the downstream energized ring network cabinet remains normally energized, and the target terminal simultaneously shows abnormal data quality, it is determined that the remote signaling change does not reflect the actual switch action, and the corresponding terminal or remote signaling acquisition circuit is determined to be abnormal.

[0233] When terminal communication is interrupted and some expected responses cannot be obtained, the status is recorded as pending confirmation. Data loss is not directly judged as a device failure. After communication is restored and the current status is obtained, the corresponding verification results are supplemented based on the restored data.

[0234] When the data of the same event sequence records meet multiple status judgment conditions at the same time, first exclude data with time abnormality, communication abnormality or device affiliation abnormality based on data quality status, and then compare topology consistency and timing integrity.

[0235] If there is a valid operating source, complete switch change and corresponding electrical response, it should be treated as a normal switching operation. If there is a protection output but the switch has not completed its operation and the fault current continues, it should be treated as a switch failure to operate. If the status change of this cabinet lacks electrical support from the adjacent ring network cabinet and is accompanied by abnormal data quality, it should be treated as a terminal abnormality.

[0236] In cases where there are both actual line anomalies and individual terminal data anomalies, the actual line status is determined by the effective electrical quantities and protection actions of the cross-ring network cabinets. At the same time, the terminal data anomaly markers are retained in the verification basis to avoid local data anomalies from obscuring power operation anomalies that have been jointly confirmed by other ring network cabinets.

[0237] Determine the power supply path where the anomaly is located. Specific details include:

[0238] When the status determination result is an abnormal upstream power supply or a fault in the downstream line, the distribution automation master station determines the power supply path where the abnormality is located in the real-time feeder topology based on the topology consistency verification result, protection action position, fault indication status and current change direction.

[0239] For downstream line faults, starting from the protection interval corresponding to the target ring network cabinet or the feeder section where the fault current occurs, trace along the current power supply direction to the power supply side and the load side respectively.

[0240] In case of upstream power supply anomalies, trace the loss of voltage or abnormal voltage state upstream from the target ring network cabinet along the current power supply path until reaching the ring network cabinet that is kept normally energized, the power supply access location, or the upstream boundary of the current monitoring range.

[0241] Determining the boundaries of the faulty section includes:

[0242] Check the fault current and fault indication status sequentially along the power supply direction from the power supply side to the load side. The upstream position where the last fault current or fault indication is detected is determined as the power supply side boundary of the fault section. The downstream position where the first fault current or fault indication is not detected, the position of the disconnecting switch in the open position, or the end of the feeder is determined as the load side boundary.

[0243] If the tracking process reaches a switch that is in a vacancy and can block the propagation of abnormality, the location of the switch is determined as the corresponding boundary. For protection devices with a clear protection range, the power supply side boundary can also be determined by combining the interval where the protection device is located and the protection direction.

[0244] When tracing the power supply path from the location of the anomaly to the load side, the location where the fault indication stops extending, the location where the fault current no longer flows, the location of the switchgear in the detachment, or the end of the feeder are determined as the load side boundary of the fault section.

[0245] When adjacent ring main units are not equipped with fault indication devices, the boundary can be determined by combining the protection action position, current change direction, switch opening and closing status and downstream undervoltage range. It is not required that each feeder section has fault indication data.

[0246] The feeder section between the power supply side boundary and the load side boundary is identified as the fault section, and the corresponding boundary switch, feeder section, and location basis are recorded in the status determination result.

[0247] Affected ring main units identified:

[0248] Based on the identified fault section, the distribution automation master station checks the current power supply path of each ring network cabinet along the real-time feeder topology;

[0249] When the power supply path of a certain ring main unit passes through the fault section, and the ring main unit experiences loss of voltage, power outage, or loss of load current, it is identified as a ring main unit affected by power outage.

[0250] When the original power supply path of a ring main unit passes through the fault section, but continues to be energized through the tie branch or backup power supply, it is identified as the affected ring main unit with a change in power supply source, and the original power supply path and backup power supply path are recorded.

[0251] Ring main units located upstream of the fault section and whose power supply status remains normal are not included in the list of affected ring main units; other feeder ring main units that do not have a current electrical connection with the fault section are also not included in the scope of impact due to geographical proximity.

[0252] The final result includes the operating status type, target ring main unit, power supply path where the anomaly is located, fault section, power supply side boundary, load side boundary, and status determination result of the affected ring main unit.

[0253] When the switch change involved in this step further causes a change in the feeder power supply relationship, first retain the verification and fault location results formed under the topology corresponding to the time of change triggering, and then submit the events whose status has not yet been assigned to the subsequent feeder topology update process, and continue to process them under the updated upstream and downstream relationship and power supply path.

[0254] The implementation includes: performing feeder topology changes, event continuation, and outputting collaborative sensing results. Specific implementation details include:

[0255] When a sectionalizing switch, tie switch, load switch, or circuit breaker changes position, the distribution automation master station confirms the actual operation of the switch based on the switch action record, remote signaling change, and the current and voltage changes of the corresponding branch. The confirmed switch change completion time is determined as the topology switching time. If only a remote signaling change is detected, but there is a lack of electrical quantity change support or the remote signaling data quality is abnormal, the corresponding branch is set to a pending confirmation state, and the feeder topology is not updated directly.

[0256] Based on the switch opening and closing status after the change, the conduction status of the corresponding branch in the primary wiring model is updated, and network connectivity analysis is performed again from the currently operational power supply point along the updated conduction branch. Combining the voltage status and active power direction of each ring main unit, the energized status and power supply direction of the updated branch are checked, and the upstream power supply ring main unit, downstream power receiving ring main unit, interconnecting ring main unit, power supply path and feeder section affiliation of each ring main unit are re-determined, generating the updated real-time feeder topology.

[0257] For the established event sequence records, events whose occurrence time is earlier than the topology switching time are associated with the real-time feeder topology before the change, and events whose occurrence time is equal to or later than the topology switching time are associated with the real-time feeder topology after the change. For events whose event collection time window spans the topology switching time and are still within the response time limit or whose status assignment has not yet been completed, the associated ring network cabinets are re-determined according to the updated upstream and downstream relationships, and records of switch change, voltage recovery, current recovery, power direction change, and communication recovery are supplemented and extracted.

[0258] Supplementary events are added to the original event sequence data according to a unified time scale, and the old and new topology identifiers corresponding to each event are retained. The topology verification and timing verification are re-executed based on the updated real-time feeder topology. When the voltage and power direction of the switchgear is restored to the backup feeder power supply direction after the tie switch is closed, and the original fault section remains isolated, the transfer process is determined to be complete.

[0259] Finally, the telemetry status, remote signaling status, switch action status, protection action status, distribution automation terminal communication status, topology verification results, timing verification results, fault sections and affected ring network cabinets of the target ring network cabinet are summarized to determine the operating status type and the cause of the status change. The collaborative perception results of the ring network cabinet operating status are output, which include the target ring network cabinet, the change trigger time, the operating status type, the fault section, the affected ring network cabinets, the original power supply path, the updated power supply path, the topology switching time, and the verification basis.

[0260] The above embodiments can be implemented, in whole or in part, by software, hardware, firmware, or any other combination thereof. When implemented using software, the above embodiments can be implemented, in whole or in part, in the form of a computer program product.

[0261] Those skilled in the art will recognize that the modules and algorithm steps of the various examples described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, or a combination of computer software and electronic hardware. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of this application.

[0262] In addition, the functional modules in the various embodiments of this application can be integrated into one processing module, or each module can exist physically separately, or two or more modules can be integrated into one module.

[0263] The above description is merely a specific embodiment of this application, but the scope of protection of this application is not limited thereto. Any variations or substitutions that can be easily conceived by those skilled in the art within the technical scope disclosed in this application should be included within the scope of protection of this application. Therefore, the scope of protection of this application should be determined by the scope of the claims.

[0264] In conclusion, the above description is only a preferred embodiment of the present invention and is not intended to limit the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the protection scope of the present invention.

Claims

1. A collaborative sensing method for the operating status of ring main units, characterized in that: The specific steps include: Collect telemetry data, remote signaling data, switch action records, protection action information and power distribution automation terminal communication status of each ring network cabinet; perform unified time stamping on the collected data and associate it according to equipment identification; and generate real-time feeder topology by combining feeder connection relationship, sectional switch status, tie switch status and current power supply mode. When a switch change, protection action, or voltage / current change is detected in the target ring main unit, the switch status change, electrical quantity change, and fault indication change that should occur in the target ring main unit and its upstream and downstream power receiving ring main units are determined based on the real-time feeder topology, switch action logic, and protection coordination relationship. Based on the time of the event, collect the remote signaling changes, telemetry changes, protection actions, and communication status of the target ring main unit, upstream and downstream power receiving ring main units, and interconnection ring main units to form event sequence record data; The event sequence record data is compared with the changes that should occur by performing topology and timing verification to determine normal switching, switch failure or malfunction, abnormal upstream power supply, fault in downstream line or abnormal distribution automation terminal, and to determine the fault section and affected ring network cabinet. When a switch change causes a change in the feeder topology, the upstream and downstream relationships and power supply paths between ring main units are updated. Based on the updated real-time feeder topology, events with incomplete state attribution are further verified, and the collaborative perception results of the ring main unit's operating status are output.

2. The collaborative sensing method for the operating status of a ring main unit according to claim 1, characterized in that: The collected data is processed with a unified time stamp and associated with device identifiers, including: Based on the time synchronization of the distribution automation master station, the system reads the acquisition time stamp and time quality identifier carried by telemetry data, remote signaling data, switch action records, protection action information, and the communication status of the distribution automation terminal. For data that meets the time synchronization requirements, the original acquisition time stamp is retained. For data that does not meet the time synchronization requirements, the time stamp is corrected according to the terminal clock deviation and a time anomaly mark is set. Establish equipment correspondence based on ring main unit identification, bay identification, switch equipment identification and distribution automation terminal identification, and associate the collected data after unified time stamping with the corresponding ring main unit and its incoming bay, outgoing bay, segment bay or tie bay. The validity status of the collected data is determined based on the data quality identifier, communication status, and the continuity of adjacent collected values ​​at the same measurement point. Abnormal data generated during periods of inconsistent device affiliation, invalid data quality, or communication interruption are set as data that do not participate in the status verification.

3. The collaborative sensing method for the operating status of a ring main unit according to claim 2, characterized in that: Generate real-time feeder topology, including: Obtain the primary wiring model of the power distribution line, and establish the electrical connection relationship between the power source point, busbar, ring main unit, switchgear and feeder section in the primary wiring model; Map the current open / closed state of the sectionalizing switch, tie switch, load switch, and circuit breaker to the primary wiring model, determine the conducting branch based on the switch equipment in the closed position, and determine the disconnected branch based on the switch equipment in the open position. Network connectivity analysis is performed along the conductive branches from the power source point. The energized status and power supply direction of the feeders are checked in conjunction with the voltage status and active power direction of each ring main unit. The upstream power supply ring main unit, downstream power receiving ring main unit, interconnection ring main unit and feeder section affiliation of each ring main unit are determined, and the real-time feeder topology is generated.

4. The collaborative sensing method for the operating status of a ring main unit according to claim 3, characterized in that: Determine the switch status changes, electrical quantity changes, and fault indication changes that should occur in the target ring main unit and its upstream and downstream energized ring main units, including: When the switch remote signal is detected to change from open to closed or from closed to open, the protection device is activated or outputs, or the change in voltage or current exceeds the corresponding change judgment threshold and continues to reach the specified acquisition cycle, the corresponding ring main unit is identified as the target ring main unit, and the corresponding change trigger time and change type are determined. Based on the type of switchgear, switch change direction, protection action type, feeder section and power supply direction of the change in the target ring main unit, call the corresponding switch action logic and protection coordination relationship; Determine the upstream power supply ring network cabinet, downstream power receiving ring network cabinet, and interconnection ring network cabinet corresponding to the target ring network cabinet along the real-time feeder topology, and determine the switch position, voltage status, current change direction, power direction, and fault indication status of each ring network cabinet respectively.

5. The collaborative sensing method for the operating status of a ring main unit according to claim 4, characterized in that: The data that forms the sequence of events includes: Based on the protection action time limit, the switching equipment action time and the data transmission delay of the power distribution automation terminal, the event collection time window is determined with the change trigger time as the benchmark. Within the event collection time window, extract the remote signaling change records, telemetry change records, switch action records, protection start records, protection output records, and distribution automation terminal communication status corresponding to the target ring network cabinet, upstream power supply ring network cabinet, downstream power receiving ring network cabinet, and interconnection ring network cabinet. The extracted records are sorted according to the event occurrence time after unified time stamp, and each record is marked with the corresponding ring main unit, switch equipment, feeder section, upstream and downstream location and data quality status. Records that occur at the same time are kept in parallel according to their source order: protection action record, switch action record, remote signaling change record, and telemetry change record, forming event sequence record data.

6. The collaborative sensing method for the operating status of a ring main unit according to claim 5, characterized in that: Perform topological verification on the event sequence record data, including: Based on the real-time feeder topology, determine the electrical connection path, switch on / off status, and power supply direction between the target ring main unit and the upstream power supply ring main unit, the downstream power receiving ring main unit, and the interconnection ring main unit; The actual switch positions, voltage status, current change direction, power direction, and fault indication status of each ring main unit in the event sequence record data are correlated with the expected changes in switch status, electrical quantity, and fault indication. When the changed ring main unit, feeder section and change direction are consistent with the electrical connection path and power supply direction, and the state change does not cross the switch equipment in the detachment position, a topology consistency verification result is generated. When the state change deviates from the current power supply path, crosses a switch device in a terminating position, or the direction of change does not match the current power supply direction, a topology inconsistency check result is generated.

7. A collaborative sensing method for the operating status of a ring main unit according to claim 6, characterized in that: Perform time-series verification on the event sequence data, including: Based on the switch action logic, protection coordination relationship, switch equipment action time and power distribution automation terminal data transmission delay, determine the prescribed order of occurrence and corresponding response time limits between protection start-up, protection output, switch position change, current change, voltage change and fault indication change; The actual order and time interval of each change in the event sequence record data are compared with the specified order and response time limit; When the switch action record, remote signal change and corresponding electrical quantity change conform to the specified occurrence sequence and are within the corresponding response time limit, it is judged as normal switching; When there is a switch action record or protection output record, and the corresponding switch equipment fails to complete the remote signaling change within the action time limit, and the current of the branch does not change according to the switch action requirements, it is determined that the switch fails to operate. When a switchgear undergoes a remote signaling change and a corresponding electrical quantity change, but there is no corresponding switch operation source or protection output record, it is determined to be a switch malfunction. When the target ring main unit and its downstream power receiving ring main units experience unidirectional voltage loss or load current drop, and the upstream power supply side of the target ring main unit simultaneously experiences voltage abnormality, it is determined to be an upstream power supply abnormality. When the upstream power supply side of the target ring main unit remains energized, and the fault current, protection action, or fault indication is concentrated in the downstream feeder section of the target ring main unit, it is determined to be a downstream line fault. When the telemetry changes or telesignal changes uploaded by the target ring main unit are not supported by the electrical status of the adjacent ring main units, and are accompanied by invalid data quality, communication interruption or time stamp abnormality, it is determined that the distribution automation terminal is abnormal.

8. A collaborative sensing method for the operating status of a ring main unit according to claim 7, characterized in that: Identify the faulty section and affected ring main units, including: When the judgment result is an abnormal upstream power supply or a fault in the downstream line, the power supply path where the abnormality is located is determined along the real-time feeder topology based on the topology consistency verification result, protection action position, fault indication status and current change direction. Tracing along the power supply path to the power supply side, the location in the adjacent feeder section where the fault current or fault indication changes to the absence of fault current or fault indication, or the location of the switching equipment that is in the separation and blocks the abnormal propagation, is determined as the power supply side boundary of the fault section. Tracing along the power supply path to the load side, the location where the fault indication stops extending, the location of the switchgear in the detachment, or the end of the feeder is determined as the load-side boundary of the fault section; The feeder section between the power supply side boundary and the load side boundary is identified as the fault section, and the ring main unit whose power supply path passes through the fault section and experiences loss of voltage, power outage or change of power source is identified as the affected ring main unit.

9. A collaborative sensing method for the operating status of a ring main unit according to claim 8, characterized in that: When a switch change causes a change in the feeder topology, the upstream and downstream relationships and power supply paths between ring main units are updated, including: The time when the switch change is completed after the timing verification is determined as the topology switching time. The conduction status of the corresponding branch in the wiring model is updated according to the switch opening and closing status after the change. The network connectivity analysis is performed again from the power source along the updated conductive branch. The updated feeder energization status and power supply direction are checked in conjunction with the voltage status and active power direction. The upstream and downstream relationships, power supply paths and feeder section affiliations of each ring network unit are then redefined. Events that occurred earlier than the topology switchover time are associated with the real-time feeder topology before the changeover, and events that occurred no earlier than the topology switchover time are associated with the real-time feeder topology after the changeover. For events whose event collection time window spans the topology switching time and whose state assignment has not yet been completed, topology verification and timing verification are re-executed according to the updated upstream and downstream relationships and power supply paths.

10. A collaborative sensing method for the operating status of a ring main unit according to claim 9, characterized in that: Output the collaborative sensing results of the ring main unit's operating status, including: Summarize the telemetry status, remote signaling status, switch action status, protection action status, power distribution automation terminal communication status, topology verification results, and time sequence verification results corresponding to the target ring network cabinet to determine the operating status type and the reasons for status changes of the target ring network cabinet; The operating status type is associated with the corresponding change trigger time, real-time feeder topology, fault section, affected ring network cabinet and event sequence record data, and the topology switching time and data quality status corresponding to the real-time feeder topology used are recorded. Based on the status classification records generated according to normal switching, switch failure to operate, switch malfunction, upstream power supply abnormality, downstream line fault or distribution automation terminal abnormality, the output is a collaborative perception result of the ring network cabinet operation status, which includes the target ring network cabinet, operation status type, occurrence time, fault section, affected ring network cabinets and verification basis.

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