Substation on-off state monitoring system based on centralized monitoring

Abstract

The invention relates to a transformer substation switch state monitoring system based on centralized monitoring, and relates to the technical field of power system automation, and the system comprises a data collection module which is used for integrating multi-source heterogeneous data; the state judgment module outputs the unique real-time comprehensive state of each switch according to the communication state, the alarm condition function and the multi-stage judgment logic of the original remote signaling; the outage diagnosis module is used for classifying events when the switch trips and automatically screening event sequence records (SOE) to position core diagnosis information; the influence domain pre-judgment module is used for determining all potential influenced switch sets through a graph traversal algorithm on the basis of a power grid topological structure when accident tripping occurs; and an interface generation module. According to the invention, through automatic integration and visual linkage of the operation state, the fault reason and the influence range of the switch, the monitoring intuition, the diagnosis accuracy and the emergency disposal decision-making efficiency are significantly improved.

Description

Technical Field

[0001] This disclosure relates to the field of power system automation technology, and in particular to a substation switch status monitoring system based on centralized monitoring. Background Technology

[0002] With the large-scale construction of new energy power plants such as wind power and photovoltaic power generation, automated and intensive operation and maintenance management has become an inevitable trend. The centralized control center uses technologies such as SCADA to centrally monitor a large number of switchgear devices in multiple remote substations that are either unmanned or minimally staffed. This model aims to improve monitoring efficiency and reduce operation and maintenance costs.

[0003] However, existing centralized monitoring systems still have significant shortcomings in terms of the intuitiveness of information presentation and the intelligence of decision support. First, the way existing technologies present equipment status is usually fragmented and overly simplified. The main monitoring interface often only uses the color or shape changes of graphic symbols to represent the two basic physical states of a switch: "closed" or "open." Meanwhile, critical alarm information that truly reflects the health of the equipment, such as the status of communication links and whether electrical parameters exceed limits, is usually buried in separate, continuously scrolling text alarm lists. This fragmented information presentation forces operators to actively and continuously associate a particular switch on the graphical interface with its information in the alarm list in their minds. This greatly increases the cognitive load on monitoring personnel, making it difficult for them to quickly and accurately form a holistic judgment on the true operating status of any given switch.

[0004] Secondly, in the event of unplanned equipment outages, i.e., accidental tripping, the existing diagnostic process for the cause of the accident largely relies on manual analysis. After observing a switch trip, operators need to manually switch to the Sequence of Events (SOE) query interface and search for and locate protection action messages strongly related to the tripping event from a massive stream of raw event information from all equipment in the entire station, relying on personal experience. This process is not only inefficient and delays the golden time for fault handling, but its accuracy is also highly dependent on the operator's professional proficiency and psychological state. In emergency scenarios, it is easy to make misjudgments or miss key information due to tension.

[0005] Finally, when a switch trips due to an accident, current technology also lacks effective automated tools for predicting the extent of the power grid impact. Operators must manually and logically deduce and check all downstream branches and related equipment that might be affected by the power outage, starting from the faulty switch and referring to static electrical primary wiring diagrams. In substations with complex electrical wiring, this manual check is not only time-consuming and labor-intensive but also carries a high risk of oversight, potentially leading to incomplete assessments of the accident's impact, which in turn affects the formulation and execution of emergency repair and restoration strategies, prolonging the overall outage time. Summary of the Invention

[0006] To address the aforementioned technical issues, this disclosure provides a substation switch status monitoring system based on centralized monitoring.

[0007] This disclosure provides a first aspect of a substation switch status monitoring system based on centralized monitoring, comprising: The data acquisition module is used to collect remote signaling data of switches, telemetry data of associated electrical parameters, equipment ledger information, power grid topology, background event messages, and files and data including fault waveform uploads. The status determination module is connected to the data acquisition module. Based on the remote signaling data and telemetry data, it constructs a multi-dimensional status model of the switch to determine the real-time comprehensive status of the switch. The shutdown diagnosis module, connected to the data acquisition module, is used to classify and diagnose the cause of a shutdown event when a switch shutdown event is detected, by combining the background event message and the equipment ledger information. The impact domain prediction module is connected to the data acquisition module and the outage diagnosis module. When the outage diagnosis module identifies a fault tripping event, it analyzes and determines the potential impact domain of the fault tripping event based on the power grid topology. The interface generation module, connected to the status determination module and the influence domain prediction module, is used to generate a centralized monitoring interface. On this interface, the switches are visualized according to the real-time comprehensive status, and special identifiers are superimposed on the switches within the potential influence domain.

[0008] As a preferred technical solution, the multi-dimensional state model of the switch constructed by the state determination module includes at least four states: communication interruption state, alarm state, closing state, and opening state; the state determination module is configured to determine the real-time comprehensive state of the switch according to the priority order of communication interruption state, alarm state, and closing / opening state.

[0009] As a preferred technical solution, the status determination module determines the status by judging a preset alarm condition function. Whether the switch enters the alarm state is determined by whether the condition is true or false. The alarm condition function is: ; in, The real-time voltage obtained from the telemetry data. The real-time current obtained from the telemetry data. and These are the preset upper and lower voltage thresholds. This is the preset upper limit threshold for current.

[0010] As a preferred technical solution, the outage diagnosis module is specifically configured to: classify the outage event as either an accidental trip or a manual outage; and, based on the switch identifier associated with the outage event, automatically search for and fill in the site name and equipment name information of the switch from the equipment ledger information.

[0011] As a preferred technical solution, when the outage event is classified as a fault trip, the outage diagnosis module is further configured to: use the switch action time... Based on this, filter time windows in the background event messages. The event log inside, To allow for a preset time margin; and to perform keyword matching on the selected event records to extract the main protection trip information as the result of the cause diagnosis; When a circuit breaker trips, the fault recorder generates a file containing complete data for a period of time before and after the fault, including: Analog quantities: voltage and current waveforms of the faulty and non-faulty phases; Switching signals: open / closed positions of relevant switches, start-up and output signals of main protection components; Timestamp: Absolute time of failure accurate to the millisecond level.

[0012] As a preferred technical solution, the influence domain prediction module is specifically configured as follows: abstracting the power grid topology into graph structure data; and, starting from the corresponding node of the switch that tripped due to an accident in the graph structure, executing a graph traversal algorithm to determine the set of switch nodes traversed as the potential influence domain.

[0013] As a preferred technical solution, the special identifier superimposed by the interface generation module assigns a temporary potential influence state to the switch within the potential influence domain, and this potential influence state is superimposed on the original state color of the switch.

[0014] As a preferred technical solution, the outage diagnosis module is further configured to calculate the cumulative outage duration of each outage event in real time. The calculation formula is: ; in, To calculate the total downtime, The current system time. The switching action time for the shutdown event; The interface generation module further generates a shutdown details interface, and on this interface, all shutdown events are sorted in descending order based on the cumulative shutdown duration.

[0015] As a preferred technical solution, the background event messages collected by the data acquisition module are Event Sequence Records (SOEs).

[0016] Secondly, the substation switch status monitoring system based on centralized monitoring provided in this application adopts the following technical solution: A second aspect of the present invention provides a method for monitoring the status of substation switches based on centralized monitoring, comprising the following steps: Collect remote signaling data of switches, telemetry data of associated electrical parameters, equipment ledger information, power grid topology, background event messages, and fault recording information; Based on the aforementioned remote signaling data and telemetry data, a multi-dimensional state model of the switch is constructed to determine the real-time comprehensive state of the switch. When a switch outage event is detected, the outage event is classified and the cause is diagnosed by combining the background event message and the equipment ledger information, and the fault recording file information is also used. When a fault trip event is identified, the potential impact domain of the fault trip event is analyzed and determined based on the power grid topology. A centralized monitoring interface is generated to visualize the switches based on the real-time comprehensive status, and special identifiers are overlaid on the switches within the potential impact area.

[0017] The technical solution provided in this disclosure has the following advantages compared with the prior art: 1. This invention establishes a status determination module that constructs a multi-dimensional status model of the switch, including alarm states, and integrates and analyzes the physical location telemetry data of the switch with its associated electrical parameter telemetry data. This approach enables the switch on the centralized monitoring interface to not only display its open / closed position but also intuitively reflect whether the electrical operating conditions of its circuit are abnormal, thereby allowing operators to identify equipment with potential operational risks in advance. 2. This invention, by setting up a shutdown diagnosis module, can automatically classify events after a switch shutdown occurs. For accidental tripping events, it filters the background event messages based on action time and keywords to extract the main cause diagnosis information. This automated processing replaces the manual search and filtering of massive event messages, shortening the time required to obtain fault cause information; 3. This invention incorporates an impact domain prediction module. After the outage diagnosis module identifies a fault trip, this module analyzes a preset power grid topology to determine a set of other devices directly electrically connected to the faulty switch. By specially marking these devices on the interface, it provides operators with direct visual guidance to assess the potential extent of the fault, assisting them in making subsequent operational decisions and thus mitigating the expansion of the fault's scope. Attached Figure Description

[0018] The accompanying drawings, which are incorporated in and form a part of this specification, illustrate embodiments consistent with this disclosure and, together with the description, serve to explain the principles of this disclosure.

[0019] To more clearly illustrate the technical solutions in the embodiments of this disclosure or the prior art, the accompanying drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, for those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0020] Figure 1 This is the system architecture diagram of this application; Figure 2 This is a flowchart of the method in this application.

[0021] Among them, 10 is the data acquisition module; 20 is the status determination module; 30 is the shutdown diagnosis module; 40 is the impact domain prediction module; and 50 is the interface generation module. Detailed Implementation

[0022] To better understand the above-mentioned objectives, features, and advantages of this disclosure, the solutions disclosed herein will be further described below. It should be noted that, unless otherwise specified, the embodiments and features described herein can be combined with each other.

[0023] Numerous specific details are set forth in the following description in order to provide a full understanding of this disclosure, but this disclosure may also be implemented in other ways different from those described herein; obviously, the embodiments in the specification are only some, and not all, of the embodiments of this disclosure.

[0024] The following is in conjunction with the appendix Figure 1 This application will be described in further detail below.

[0025] Example 1: A substation switch status monitoring system based on centralized monitoring, comprising: The data acquisition module 10 is used to acquire remote signaling data of switches, telemetry data of associated electrical parameters, equipment ledger information, power grid topology, background event messages and fault recording information; The data acquisition module 10 is responsible for acquiring and integrating all the data required by the system from multiple heterogeneous data sources. The execution process of this module includes subscribing to real-time dynamic data streams and extracting static configuration data.

[0026] For real-time dynamic data and fault recordings, the data acquisition module 10 establishes a communication connection with the monitoring host of the power plant or the SCADA system backend of the central control center via a network interface. In one embodiment, this communication follows power industry standard communication protocols such as IEC60870-5-104 or Modbus TCP / IP. The module acquires two types of core real-time data from these sources: The first category is remote signaling data, which includes the two-point remote signaling position signal of each switch (for example, the value "01" represents the open position and the value "10" represents the closed position), as well as communication status signals used to characterize the communication link status between the equipment and the monitoring system.

[0027] The second category is telemetry data, which consists of analog electrical quantities associated with each switch's electrical circuit or bay, specifically including three-phase voltage values, three-phase current values, and active power values. All acquired real-time data is timestamped to the millisecond level.

[0028] For static configuration data, the data acquisition module 10 performs two data acquisition tasks: First, the module retrieves equipment ledger information. It accesses the equipment asset management database via a database connection (e.g., ODBC or JDBC interface) or imports equipment ledgers for all monitored objects by parsing a pre-defined configuration file (e.g., XML or CSV file). The ledger information provides each switch with a unique equipment identifier (ID) and associates it with static attributes such as its site name, standard equipment name, voltage level, and assigned bay. This equipment identifier is the key for all subsequent data associations.

[0029] Secondly, the module obtains the power grid topology. Similarly, it imports the electrical connections of the power grid from a design database or configuration file. This topology is parsed and stored as a graph data structure, such as an adjacency list. In this structure, each switch, busbar, or line segment is defined as a node, and the physical electrical connections between nodes are defined as edges of the graph.

[0030] The data acquisition module 10 also continuously listens for and receives Event Sequence Record (SOE) message streams from the background event server. Each SOE message contains a timestamp accurate to milliseconds, an associated device identifier, and text information describing the event content. The data acquisition module 10 stores the received SOE messages in a pre-defined, first-in-first-out circular buffer to ensure that all event records within the most recent period can be immediately accessed by the shutdown diagnostic module 30.

[0031] After data acquisition is completed, the data acquisition module 10 performs preliminary data integration. Using device identifiers as indexes, it associates the real-time acquired remote signaling and telemetry data with static device ledgers and topology information to form structured data objects. These integrated data objects are then distributed to the status determination module 20, the shutdown diagnosis module 30, and the impact domain prediction module 40 as inputs for their respective subsequent processing.

[0032] The status determination module 20 is connected to the data acquisition module. Based on remote signaling data and telemetry data, it constructs a multi-dimensional status model of the switch to determine the real-time comprehensive status of the switch. The status determination module 20 receives structured data objects from the data acquisition module 10, which are integrated for each switch entity. The core function of this module is to periodically calculate and output a unique real-time integrated status for each switch. This calculation process follows a decision-making flow with clear priorities.

[0033] The first step in the decision-making process, and the highest priority judgment, is a communication status check. The status judgment module 20 first checks the communication status signal in the switch entity data object. If the signal indicates that the communication link is abnormal or interrupted, the real-time integrated status of the switch is directly judged as a communication interruption state. Once this judgment is made, the subsequent decision-making process terminates, and the module immediately outputs the result to the interface generation module 50.

[0034] If the communication status signal is normal, the decision-making process proceeds to the second step, namely, electrical alarm judgment. The status judgment module 20 executes an alarm condition function. The calculation determines whether there are any abnormalities in the electrical parameters associated with the switch. The result of this function is a Boolean value; when it is true, the real-time overall status of the switch is determined to be in an alarm state. Alarm condition function. The complete expression is as follows:

[0035] in: Real-time voltage values ​​obtained from telemetry data; Real-time current value obtained from telemetry data; Real-time active power values ​​obtained from telemetry data; , These are the preset upper and lower voltage engineering thresholds; : This is the preset upper limit engineering threshold for current; The original position remote signal of the switch: a value of 1 represents closing and a value of 0 represents opening. A tiny positive threshold used to determine whether the current is zero, used to handle sensor zero-point drift; A tiny power threshold used to determine whether power transfer is occurring; : Represents telemetry sampled value Within a preset time length No numerical changes occurred within.

[0036] The above alarm condition function In the logical structure of the expression This is used to detect a specific abnormal operating condition of equipment, such as a broken secondary circuit in a current transformer (CT). In this condition, the switch is in the closed position and there is actual power transmission on the line, but the measured current value is close to zero. The expression ( This is used to detect data freeze faults, that is, a failure of the front-end unit or sensor of the monitoring system, which causes the uploaded telemetry data to remain constant for a period of time.

[0037] If the communication status is normal and the alarm condition function is valid If the calculation result is false, the decision-making process proceeds to the third step, which is based on the original position remote signaling signal of the switch. Determine its fundamental physical state. If If the value is 1, the real-time integrated status of the switch is determined to be in the closed state. If If the value is 0, the real-time integrated status of the switch is determined to be in the open state.

[0038] In summary, after the state determination module 20 executes a complete decision-making process for each switch, it outputs a deterministic state result selected from the set {communication interruption state, alarm state, closed state, open state}. This result is then passed to the interface generation module 50 for subsequent visualization rendering.

[0039] The shutdown diagnosis module 30 is connected to the data acquisition module and is used to classify and diagnose the cause of the shutdown event by combining the background event message and the equipment ledger information when a shutdown event is detected. The outage diagnosis module 30 automatically detects, classifies, and diagnoses the causes of switch outage events. This module continuously receives remote signaling signals, including the original switch position, from the data acquisition module 10. The data stream.

[0040] This module monitors each switch. Signal sequences are used to detect shutdown events. When a switch... A shutdown event is detected when a signal undergoes a clear transition from value 1 (representing closing) to value 0 (representing opening). The module immediately captures and records the timestamp of this transition, denoted as the switch action time. .

[0041] Upon detecting a shutdown event, the shutdown diagnosis module 30 first performs event classification. The classification is based on the timing of the switch's operation. A preset time window before it occurs Does the switch identifier have a specific operation record associated with it? A preset command time window, such as 5 seconds, is defined. Within this time window, the module checks for remote tripping command records or planned shutdown flags, and verifies the fault waveform file for any tripping events. If such records are found, the shutdown event is classified as a manual shutdown. If no such records are found, the event is initially classified as an accidental trip.

[0042] After the event is categorized, the module immediately performs automatic information association. It uses the switch identifier that triggered the event to extract the corresponding equipment ledger information from the structured data object provided by the data acquisition module 10, and fills the outage record generated for this event with static attributes such as site name, equipment standard naming, and voltage level.

[0043] For events classified as fault trips, the outage diagnosis module 30 initiates a cause diagnosis filtering algorithm. This algorithm extracts a signal from the SOE message circular buffer provided by the data acquisition module 10 that matches the fault trip site or the trip interval, based on the switch action time. The time segment centered on [the time frame]. The range of this time segment is defined as [the time segment's scope]. ,in This is a preset time margin, such as 2 seconds, to accommodate system time errors and communication delays.

[0044] Next, the module performs content matching on SOE message records within the selected time segment that match the tripped site or trip interval of the incident. Internally, the module maintains a predefined set of protection action keywords. This set contains text strings such as "protection action," "overcurrent section," "instantaneous trip," "heavy gas," "differential protection," and "distance protection." The algorithm iterates through each SOE message within the segment that matches the tripping station or the tripping interval of the fault, and compares its text content with the set. The keywords in the message are used for substring matching. All successfully matched message records are extracted as core diagnostic information representing the main cause of the tripping incident, and then populated into the outage record for that event.

[0045] For all active outage events, the outage diagnosis module 30 also calculates the cumulative outage duration. A timer within the module periodically triggers this calculation. Each calculation uses the current system time. Subtract the on / off action time of the event The total downtime was obtained. The calculation results are continuously updated in the corresponding outage records.

[0046] In a more enhanced embodiment, when performing cause diagnosis, the outage diagnosis module 30, in addition to the SOE message filtering described above, also performs the following linkage analysis steps: First, based on the switch identifier of the fault trip and the event occurrence time... The system invokes data acquisition module 10 to request the associated fault waveform data file. Upon successful file acquisition, the module performs preliminary automated analysis of the waveform data, extracting key electrical characteristics such as fault type (e.g., single-phase grounding, phase-to-phase short circuit), fault phase, and peak fault current. These features, directly analyzed from the waveform data, are cross-validated and integrated with protection action information filtered from SOE messages to form a more detailed and accurate core diagnostic information, thereby significantly improving the accuracy and information dimensionality of the diagnosis.

[0047] Finally, the outage diagnosis module 30 outputs a structured outage record for each outage event. This record includes the switch identifier, event category (fault trip or manual outage), core diagnostic information (if it is a fault trip), and dynamically updated cumulative outage duration. This structured record is simultaneously sent to the impact domain prediction module 40 and the interface generation module 50.

[0048] The impact domain prediction module 40 is connected to the data acquisition module and the outage diagnosis module. It is used to analyze and determine the potential impact domain of the outage trip event based on the power grid topology when the outage diagnosis module identifies the accident trip event. The execution of the impact domain prediction module 40 is triggered by the output of the outage diagnosis module 30. The outage diagnosis module 30 initiates its analysis process only when it outputs an outage record classified as "fault trip". Upon startup, the module receives the switch identifier associated with the fault trip event.

[0049] The data required for the module's analysis includes two parts: one part is the switch identifier from the outage diagnosis module 30; the other part is the pre-loaded and parsed power grid topology data from the data acquisition module 10. In this embodiment, the topology is stored as a graph data structure, specifically an adjacency list. In this adjacency list, each electrical device, including switches, buses, transformers, and line segments, corresponds to a unique node in the graph; if two devices are physically directly connected, there is an edge between their corresponding nodes.

[0050] The core analysis process of the influence domain prediction module 40 is a graph traversal algorithm. In this embodiment, a breadth-first search (BFS) algorithm is used. The execution steps of this algorithm are as follows: Initialization. Based on the switch identifier of the triggering event, locate its corresponding starting node in the graph structure, denoted as . Create a queue to store nodes to be visited, and... Add to the queue. Simultaneously, create a set to store nodes within the identified potential influence domains, denoted as . and will Add to the collection.

[0051] Iterate through the queue. Perform the following operation if and only if the queue is not empty: Take a node from the head of the queue and denote it as the current node. .

[0052] Access the stored adjacency list to find the node with respect to the current node. All directly connected neighboring nodes.

[0053] For each neighbor node Check if it exists in the set. If it does not exist, then the neighbor node will be... Simultaneously added to the tail of the queue and the set middle.

[0054] Termination. The loop traversal terminates when the queue is empty. At this point, the set... It includes the starting node Starting from, all reachable electrical equipment nodes on the power grid topology.

[0055] After the algorithm finishes execution, the module processes the set. A filtering operation is performed. It iterates through each node in the set and, based on the node's attribute information, filters out all nodes of type "switch". This set of filtered switch nodes constitutes the final potential impact domain of this tripping event.

[0056] Finally, the influence domain prediction module 40 outputs the identifiers of all switches in the potential influence domain as a list or set. This output is then sent to the interface generation module 50 for subsequent visualization processing.

[0057] The interface generation module 50 is connected to the status determination module and the influence domain prediction module. It is used to generate a centralized monitoring interface. On this interface, the switches are visualized according to the real-time comprehensive status, and special markings are superimposed on the switches in the potential influence domain.

[0058] The interface generation module 50 is responsible for rendering and managing these two user interfaces, and integrating data from the status determination module 20, the shutdown diagnosis module 30, and the impact domain prediction module 40 for linked display.

[0059] For the centralized monitoring main interface, the interface generation module 50 designs it as a two-dimensional matrix layout. Each cell of the matrix uniquely corresponds to a monitored switch entity. This module periodically receives the real-time comprehensive status output by the status determination module 20 for each switch and renders the background color of the corresponding cell according to a preset color mapping rule. In this embodiment, the mapping rule is defined as: A green background indicates the circuit is closed; a red background indicates the circuit is open; and a yellow background indicates an alarm. A gray background indicates a communication interruption. This method allows the interface to macroscopically display the status distribution of all switches.

[0060] The outage details interface displays all active outage events in a table format. The interface generation module 50 receives structured outage records from the outage diagnosis module 30. Each row in the table corresponds to an outage event, and the columns include: sequence number, site name, equipment standard name, event occurrence time, event category, core diagnostic information, and dynamically updated cumulative outage duration. The module has a built-in timer whose period is synchronized with the refresh cycle of the cumulative outage duration in the outage diagnosis module 30. Whenever updated duration data is received, the interface generation module 50 immediately sorts all rows in the table in descending order based on the value of the "cumulative outage duration" column, ensuring that the event with the longest outage time is always displayed at the top of the table.

[0061] One of the core functions of the interface generation module 50 is to achieve information linkage. When the influence domain prediction module 40 outputs a list of potential influence domains containing multiple switch identifiers, the interface generation module 50 performs the following operations: It iterates through each switch identifier in the list and locates the corresponding cell in the two-dimensional matrix of the central monitoring interface. Then, it overlays a preset special identifier onto these cells. In this embodiment, the special identifier is a semi-transparent blue flashing animation effect rendered on top of the cell's existing background color.

[0062] This linkage mechanism allows a switch in the "closed state" (green background) to display a flashing blue animation on its cell if it is determined to be within a potential influence zone, while maintaining the green background. This overlay display method directly and visually links the diagnostic results of the fault tripping event (via the influence zone prediction module 40) with the global status monitoring. The special overlay indicator is removed once the fault has been resolved or the preset timeout conditions are met.

[0063] The outage details interface provides an interactive "confirm" control for each outage event row. After the operations staff has completed the analysis or processing of the event, activating the control changes the background color of the row in the outage details interface to gray, and the cumulative outage duration stops updating. This record is the first confirmed event.

[0064] See attached document Figure 2 , Figure 2 This is a flowchart of a substation switch status monitoring method based on centralized monitoring according to an embodiment of the present invention. The method includes the following steps: S1. Collect and integrate the data required by the system. This step obtains real-time remote signaling and telemetry data from all switches through standard communication protocol interfaces, acquires equipment ledger information and power grid topology through database interfaces or file parsing methods, and continuously receives SOE messages from the background event server that match the event sequence records of the tripped site or the tripped interval. Then, using a unique equipment identifier as the key, the data from the above different sources are associated to form a structured data object for use in subsequent steps.

[0065] S2. Periodically determine the real-time overall status of each switch. For each switch, the determination is performed in the following priority order: First, check its communication status signal. If the signal indicates a communication interruption, the real-time integrated status of the switch is determined to be a communication interruption state, and the current determination process for this switch ends.

[0066]

[0067] If function If the result is true, the real-time integrated status of the switch is determined to be in an alarm state. If communication is normal and there is no alarm, the original position remote signaling signal is used. The value determines the real-time integrated status of the switch as the closed state. (1) or tripped state ( (0). The output of this step is a deterministic state for each switch.

[0068] S3. Detect, classify, and record outage events. This step continuously monitors the position remote signaling signals of all switches.

[0069] When any switch signal is detected to transition from closed to open, the switch action time is recorded. and according to If a remote tripping command record exists within the time window, classify the event as either a manual shutdown or an accident trip. Simultaneously, extract information from the equipment ledger based on the switch identifier to generate an initial shutdown record containing the site, equipment name, event category, and action time.

[0070] S4. Perform cause diagnosis and impact domain prediction if and only if the event classified in S3 is an accident trip.

[0071] In terms of cause diagnosis, extract from the SOE message cache that matches the tripped site of the incident or the tripped interval. Message records within the time window, and using a predefined set of protection action keywords. Matching is performed, and successfully matched messages are used as diagnostic results. Regarding impact domain prediction, starting from the corresponding node of the switch that tripped due to the fault in the pre-loaded power grid topology, a graph traversal algorithm (e.g., breadth-first search) is executed to find all electrically connected nodes, and the switch nodes among them are selected to form a list of potential impact domains.

[0072] S5. Generate and update the user interface. This step includes: continuously rendering the background color of each switch on the centralized monitoring main interface according to the real-time comprehensive status output by S2, using a preset color mapping rule. When an outage record is generated in S3, add a new row to the outage details interface and fill in its site, equipment, category, and diagnostic results output by S4. Simultaneously, periodically calculate and update the cumulative outage duration of this record. The list is then sorted in descending order based on the duration. After S4 outputs the list of potential impact areas, a preset special visual identifier (such as a semi-transparent blue flashing animation) is overlaid on the graphic unit corresponding to all switches in the list on the centralized monitoring main interface to achieve information linkage.

[0073] It should be noted that, in this document, relational terms such as "first" and "second" are used merely to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitations, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes said element.

[0074] The above description is merely a specific embodiment of this disclosure, enabling those skilled in the art to understand or implement it. Various modifications to these embodiments will be readily apparent to those skilled in the art, and the general principles defined herein may be implemented in other embodiments without departing from the spirit or scope of this disclosure. Therefore, this disclosure is not to be limited to the embodiments described herein, but is to be accorded the widest scope consistent with the principles and novel features disclosed herein.

Claims

1. A substation switch status monitoring system based on centralized monitoring, characterized in that, include: The data acquisition module is used to collect remote signaling data of switches, telemetry data of associated electrical parameters, equipment ledger information, power grid topology, background event messages, and files and data including fault waveform uploads. The status determination module is connected to the data acquisition module. Based on the remote signaling data and telemetry data, it constructs a multi-dimensional status model of the switch to determine the real-time comprehensive status of the switch. The shutdown diagnosis module, connected to the data acquisition module, is used to classify and diagnose the cause of a shutdown event when a switch shutdown event is detected, by combining the background event message and the equipment ledger information. The impact domain prediction module is connected to the data acquisition module and the outage diagnosis module. When the outage diagnosis module identifies a fault tripping event, it analyzes and determines the potential impact domain of the fault tripping event based on the power grid topology. The interface generation module, connected to the status determination module and the influence domain prediction module, is used to generate a centralized monitoring interface. On this interface, the switches are visualized according to the real-time comprehensive status, and special identifiers are superimposed on the switches within the potential influence domain.

2. The substation switch status monitoring system based on centralized monitoring according to claim 1, characterized in that, The switch multidimensional state model constructed by the state determination module includes at least four states: Communication interruption status, alarm status, closed status, and open status; The status determination module is configured to determine the real-time comprehensive status of the switch according to the priority order of communication interruption status, alarm status, and closing or opening status.

3. The substation switch status monitoring system based on centralized monitoring according to claim 1, characterized in that, The state determination module determines whether the switch enters the alarm state by judging whether a preset alarm condition function is true. The alarm condition function is: ； in, The real-time voltage obtained from telemetry data. The real-time current obtained from telemetry data, and These are the preset upper and lower voltage thresholds. This is the preset upper limit threshold for current.

4. A substation switch status monitoring system based on centralized monitoring according to claim 1, characterized in that, The specific configuration of the outage diagnosis module is as follows: The outage events are classified as accidental tripping or manual shutdown. Based on the switch identifier associated with the outage event, the site name and equipment name information of the switch are automatically retrieved and populated from the equipment ledger information.

5. A substation switch status monitoring system based on centralized monitoring according to claim 4, characterized in that, When the outage event is classified as a fault trip, the outage diagnosis module is further configured as follows: Based on the switching action time Based on this, filter time windows in the background event messages. The event log inside, This is a preset time margin; Keyword matching is performed on the selected event records to extract the main protection trip information as the result of cause diagnosis; When a circuit breaker trips, the fault recorder generates a file containing complete data for a period of time before and after the fault, including: Analog quantities: voltage and current waveforms of the faulty and non-faulty phases; Switching signals: open / closed positions of relevant switches, start-up and output signals of main protection components; Timestamp: Absolute time of failure accurate to the millisecond level.

6. A substation switch status monitoring system based on centralized monitoring according to claim 1, characterized in that, The influence domain prediction module is specifically configured as follows: The power grid topology is abstracted into graph-structured data; Starting from the corresponding node in the graph structure of the switch that tripped due to the accident, a graph traversal algorithm is executed to determine the set of switch nodes reached during the traversal as the potential influence domain.

7. A substation switch status monitoring system based on centralized monitoring according to claim 6, characterized in that, The special identifier superimposed by the interface generation module assigns a temporary potential influence state to the switches within the potential influence domain. This potential influence state is superimposed on the original state color of the switch.

8. A substation switch status monitoring system based on centralized monitoring according to claim 1, characterized in that, The outage diagnosis module is also configured to calculate the cumulative outage duration of each outage event in real time, using the following formula: ； in, To calculate the total downtime, The current system time. The switching action time for the shutdown event; The interface generation module further generates a shutdown details interface, and on this interface, all shutdown events are sorted in descending order based on the cumulative shutdown duration.

9. A substation switch status monitoring system based on centralized monitoring according to claim 1, characterized in that, The background event messages collected by the data acquisition module are Event Sequence Records (SOEs).

10. A method for monitoring the status of substation switches based on centralized monitoring, comprising the substation switch status monitoring system based on centralized monitoring according to any one of claims 1-9, characterized in that, Includes the following steps: Collect remote signaling data of switches, telemetry data of associated electrical parameters, equipment ledger information, power grid topology, and background event messages; Based on the aforementioned remote signaling data and telemetry data, a multi-dimensional state model of the switch is constructed to determine the real-time comprehensive state of the switch. When a switch outage event is detected, the outage event is classified and the cause is diagnosed by combining the background event message and the equipment ledger information. When a fault trip event is identified, the potential impact domain of the fault trip event is analyzed and determined based on the power grid topology. A centralized monitoring interface is generated to visualize the switches based on the real-time comprehensive status, and special identifiers are overlaid on the switches within the potential impact area.

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