A method, device, electronic equipment, and storage medium for automated monitoring of power distribution networks.

Abstract

This invention provides a method, device, electronic equipment, and storage medium for power distribution network automation monitoring. The method includes: determining each automated switchgear on the faulty line and its initial switch state before the fault occurs based on the real-time operation mode of a fault event; taking any automated switchgear involved in a power outage simulation operation sequence associated with the fault event as the target switchgear, and determining the final expected switch state after executing the target power outage simulation operation based on the operation instruction type and the initial switch state; determining an action anomaly judgment result based on the final expected switch state of each automated switchgear in the power outage simulation operation and its actual action information within the fault event time window; and generating a fault handling logic flow based on the power supply path connectivity updated based on the final expected switch state to obtain the power supply impact range after the operation and the action anomaly judgment result. This invention improves the traceability and logical consistency of the fault handling process.

Description

Technical Field

[0001] This invention relates to the field of computer technology, and in particular to a method, apparatus, electronic device, and storage medium for automated monitoring of power distribution networks. Background Technology

[0002] In the power system, the distribution network is a key link connecting the transmission network and users, and its level of automation monitoring directly affects the reliability of power supply, power quality and operation and maintenance efficiency.

[0003] In existing power distribution network automation monitoring, a typical method is to perform fault isolation and power restoration based on a preset feeder topology and offline operation tickets. This method is usually based on a static network model, simulating a sequence of switching operations at the dispatching end and generating a power restoration path accordingly.

[0004] However, because this method does not take into account the actual operating mode at the time of the fault and the actual action behavior of the automatic switch, it cannot verify whether the executed operation sequence is consistent with the physical response on site, resulting in a lack of traceability and logical consistency in the fault handling process. Summary of the Invention

[0005] This invention provides a method, device, electronic equipment, and storage medium for automated monitoring of power distribution networks, aiming to improve the traceability and logical consistency of the fault handling process.

[0006] In a first aspect, the present invention provides a method for automated monitoring of power distribution networks, comprising:

[0007] Based on the real-time operation mode of the faulty line corresponding to the fault event at the time of the fault occurrence, determine each automated switchgear on the faulty line and its initial switching state before the fault occurred.

[0008] Taking any target power outage simulation operation in the power outage simulation operation sequence associated with the fault event as the target switchgear, the final expected switchgear state after the target power outage simulation operation is determined based on the operation instruction type and initial switch state of the target switchgear.

[0009] The power supply path connectivity is updated based on the final expected switch state to obtain the power supply impact range after the operation. Based on the final expected switch state of each automated switch device in the corresponding power outage simulation operation and its actual action information within the fault event time window, the action anomaly judgment result is determined.

[0010] Based on the power supply impact range after the operation and the abnormal action determination result, a fault handling logic flow is generated for the fault event.

[0011] In a second aspect, the present invention also provides a distribution network automation monitoring device for implementing the distribution network automation monitoring method as described in the first aspect; the distribution network automation monitoring device includes:

[0012] The fault monitoring module is used to determine each automated switchgear on the faulty line and its initial switching state before the fault occurred, based on the real-time operating mode of the faulty line corresponding to the fault event at the time of the fault occurrence.

[0013] The switch status monitoring module is used to determine the final expected switch status of the target switch after executing the target power outage simulation operation, based on the operation instruction type and initial switch status of the target switch, taking any target power outage simulation operation corresponding to the target switch in the power outage simulation operation sequence associated with the fault event.

[0014] The action anomaly analysis module is used to update the power supply path connectivity based on the final expected switch state, obtain the power supply impact range after the operation, and determine the action anomaly judgment result based on the final expected switch state of each automated switch device in the corresponding power outage simulation operation and its actual action information within the fault event time window.

[0015] The fault handling module is used to generate a fault handling logic flow for the fault event based on the power supply impact range after the operation and the abnormal action determination result.

[0016] Thirdly, the present invention also provides an electronic device, comprising: a memory for storing computer software programs; and a processor for reading and executing the computer software programs, thereby realizing the power distribution network automation monitoring method as described above.

[0017] Fourthly, the present invention also provides a non-transitory computer-readable storage medium storing a computer software program, which, when executed by a processor, implements the distribution network automation monitoring method described above.

[0018] Fifthly, the present invention also provides a computer program product, including a computer program that, when executed by a processor, implements the power distribution network automation monitoring method as described above.

[0019] The distribution network automation monitoring method provided in this invention accurately locks the target switchgear corresponding to the target power outage simulation operation based on the initial switch state of each automated switchgear on the faulty line. It obtains the final expected switch state after executing the target power outage simulation operation by combining the operation instruction type of the target switchgear. Based on the final expected switch state, the power supply path connectivity can be updated to obtain the power supply impact range after the operation. Based on the final expected switch state and the actual action information of each automated switchgear within the fault event time window, the action anomaly judgment result can be determined. Based on the power supply impact range after the operation and the action anomaly judgment result, a fault handling logic flow for the fault event is generated. This realizes fault handling from real-time operation data acquisition at the time of fault occurrence to operation expectation state deduction, actual action verification, and full-process logic sorting. The fault handling process no longer relies on static network models and offline operation tickets, but combines the real operation mode at the time of fault occurrence and the actual action behavior of the automated switches, achieving consistency verification between the operation sequence and the on-site physical response, and improving the traceability and logical self-consistency of the fault handling process. Attached Figure Description

[0020] Figure 1 This is a flowchart illustrating the power distribution network automation monitoring method provided in an embodiment of the present invention;

[0021] Figure 2 This is a schematic diagram of the structure of the power distribution network automation monitoring device provided in an embodiment of the present invention;

[0022] Figure 3 An embodiment diagram of the electronic device provided in this invention;

[0023] Figure 4 An embodiment diagram of a computer-readable storage medium provided in accordance with the present invention. Detailed Implementation

[0024] 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.

[0025] Optionally, see Figure 1 , Figure 1 This is a flowchart illustrating the distribution network automation monitoring method provided by the present invention. In this embodiment, the executing entity of the distribution network automation monitoring method is a distribution network monitoring device. Therefore, the distribution network automation monitoring method includes:

[0026] Step 10: Based on the real-time operating mode of the faulty line corresponding to the fault event at the time of the fault occurrence, determine each automated switchgear on the faulty line and its initial switching state before the fault occurred.

[0027] Optionally, the distribution network monitoring device responds to a fault event and locates the faulty line corresponding to the fault event. The faulty line refers to the distribution network line segment where a fault occurs, causing abnormal power supply. This line segment is determined by the distribution network monitoring device through a fault location system. The fault location system is a component of the distribution network monitoring device and is used to identify the specific line range where the fault occurred based on electrical quantity data such as fault current and voltage.

[0028] Furthermore, the distribution network monitoring device acquires the real-time operating mode of the faulty line at the moment the fault occurs. The real-time operating mode refers to the comprehensive operating information such as the overall power supply topology of the distribution network where the faulty line is located, the operating parameters of each device (such as voltage level and load current), and the operating status of the switching equipment at the moment the fault occurs. This information is collected and stored in real time by the distribution network monitoring device through various sensors (such as current sensors and voltage sensors) and communication modules deployed in the distribution network.

[0029] Furthermore, based on the faulty line and its real-time operation at the time of the fault, the distribution network monitoring device further identifies each automated switchgear on the faulty line. Automated switchgear refers to distribution network switchgear with remote control and status feedback functions, which can receive operation commands from the distribution network monitoring device and perform switch opening and closing actions, while feeding back its own switch status information to the distribution network monitoring device. This includes pole-mounted vacuum circuit breakers, ring main unit switches, sectionalizing switches, and other types.

[0030] Furthermore, the distribution network monitoring device acquires the initial switching state of each identified automated switchgear before the fault occurs. The initial switching state refers to the stable open / closed state of the automated switchgear before the moment the fault occurs, which is divided into two types: closed state and open state. The closed state refers to the state in which the moving and stationary contacts of the switchgear are in contact and can conduct current, while the open state refers to the state in which the moving and stationary contacts of the switchgear are separated and cannot conduct current. This initial switching state is extracted by the distribution network monitoring device from the real-time collected equipment status data, specifically the last stable switching state record before the moment the fault occurs.

[0031] In one embodiment, a phase-A ground fault occurs in a distribution network area. The distribution network monitoring device, through the fault location system, determines that the faulty line corresponding to the fault event is the 10 kV Chengdong line based on the current change data and voltage drop data of the faulty line. The distribution network monitoring device, through its own sensors and communication modules, obtains the real-time operating mode of the 10 kV Chengdong line at the time of the fault occurrence (14:30:00). The operating mode is as follows: the 10 kV Chengdong line is supplied by the 10 kV outgoing line bay of the Chengdong substation. There are 3 distribution substations connected to the line, with load currents of 120 amps, 80 amps, and 150 amps respectively. The line voltage level is 10 kV, and the overall power supply topology is radial.

[0032] Furthermore, based on the aforementioned faulty line and real-time operating mode, the distribution network monitoring device identified a total of four automated switchgear units on the 10 kV Chengdong line: Chengdong No. 1 section switch located at the beginning of the line, Chengdong No. 2 section switch located between distribution transformer substations No. 1 and No. 2, Chengdong No. 3 section switch located between distribution transformer substations No. 2 and No. 3, and Chengdong No. 4 section switch located at the end of the line. All four units are pole-mounted vacuum circuit breaker type automated switchgear.

[0033] Furthermore, the distribution network monitoring device extracted the stable status records of the above four automated switchgear before the fault occurred (14:29:59) and determined that the initial switch status was closed, that is, the moving and stationary contacts of the four switchgear were in the state of contact conduction current.

[0034] Step 20: Taking any target power outage simulation operation in the power outage simulation operation sequence associated with the fault event as the target switchgear, determine the final expected switchgear state after the target power outage simulation operation is executed based on the operation instruction type and initial switch state of the target switchgear.

[0035] Optionally, the distribution network monitoring device acquires a power outage simulation operation sequence associated with the fault event. This power outage simulation operation sequence refers to a pre-set sequence of multiple sequentially executed power outage operation steps, each corresponding to the operation of an automated switching device.

[0036] Furthermore, the distribution network monitoring device selects any target power outage simulation operation from the power outage simulation operation sequence, and identifies the automated switchgear corresponding to the target power outage simulation operation as the target switchgear. Here, the target power outage simulation operation refers to any power outage operation step selected from the sequence.

[0037] Furthermore, the distribution network monitoring device acquires the operation instruction type of the target switchgear. The operation instruction type refers to the type of operation command issued by the distribution network monitoring device to the target switchgear, which is divided into two types: opening instruction and closing instruction. Combined with the initial switching state of the target switchgear determined in step 10, and according to the basic logic of switchgear operation, the final expected switching state of the target switchgear after executing the target power outage simulation operation is determined, as shown in steps 201 to 204.

[0038] Step 30: Update the power supply path connectivity based on the final expected switch state to obtain the power supply impact range after the operation, and determine the action anomaly judgment result based on the final expected switch state of each automated switch device in the corresponding power outage simulation operation and its actual action information within the fault event time window.

[0039] Optionally, the distribution network monitoring device updates the power supply path connectivity of the distribution network based on the final expected switch state. The power supply path connectivity refers to the current conduction path relationship formed by the connection between each power supply node in the distribution network through lines and switching equipment. The update process is to adjust the on / off state of the corresponding power supply path according to the opening and closing status of the final expected switch state and determine the power supply impact range after the operation. Therefore, the power supply impact range after the operation refers to the area in the distribution network that loses power supply or whose power supply status changes after the target power outage simulation operation is performed.

[0040] Furthermore, the distribution network monitoring device acquires the actual action information of each automated switchgear within the fault event time window. The fault event time window refers to the time period from the time the fault occurs to the time the fault handling operation is completed. This time period is preset by the distribution network monitoring device according to the fault type and handling process, and is generally within 30 minutes after the fault occurs.

[0041] Optionally, the actual action information includes remote signaling change information, remote control execution feedback information, whether a remote signaling change event exists, and the direction of the remote signaling change event. Among them, remote signaling change information refers to the information that the state of the automated switchgear changes from one stable state to another stable state; remote control execution feedback information refers to the result feedback information after the automated switchgear receives and executes the remote control command of the distribution network monitoring device; remote signaling change event refers to the specific event that exists; and remote signaling change direction refers to the direction of change of the switch state from closed to open or from open to closed.

[0042] Furthermore, the distribution network monitoring device compares the final expected switching state of each automated switchgear in the corresponding power outage simulation operation with the aforementioned actual action information, and determines the action anomaly judgment result based on the comparison result, as detailed in steps 301 to 302. The action anomaly judgment result is used to determine whether the automated switchgear is in one of three states: refusal to operate, erroneous operation, or no-operation anomaly. Refusal to operate refers to the automated switchgear failing to execute the operation command as expected and maintaining the initial switching state unchanged. Erroneous operation refers to the automated switchgear executing the switching action without receiving the operation command or receiving an incorrect operation command. No-operation anomaly refers to the automated switchgear's actual action being consistent with the final expected switching state.

[0043] Step 40: Based on the power supply impact range after the operation and the abnormal action judgment results, generate a fault handling logic flow for the fault event.

[0044] Optionally, the power distribution network monitoring device sorts out the core logic nodes for fault handling based on the power supply impact range and abnormal action judgment results after the operation. The core logic nodes include fault location confirmation node, switch operation execution node, power supply impact assessment node, and abnormal handling trigger node.

[0045] Furthermore, the distribution network monitoring device generates a fault handling logic flow for the current fault event based on the sequence and correlation of each core logical node, combined with the safety specifications and operating procedures for distribution network fault handling, as described in steps 401 to 404. Optionally, the fault handling logic flow in this embodiment of the invention needs to clearly define the execution conditions, operation objects, expected results, and abnormal handling plans for each handling step, providing clear logical guidance for distribution network operation and maintenance personnel to carry out fault handling work.

[0046] This invention enables fault handling to proceed from real-time operational data acquisition at the moment of fault occurrence to deduction of expected operational states, verification of actual actions, and logical analysis of the entire process. This eliminates reliance on static network models and offline operation tickets, instead combining the actual operational mode at the moment of fault occurrence with the actual action behavior of automated switches. This achieves consistency verification between the operation sequence and the on-site physical response, improving the traceability and logical self-consistency of the fault handling process.

[0047] Optionally, the processes of steps 201 to 204 include:

[0048] Step 201: Based on the switching action direction indicated in the operation instruction type and the initial switching state, determine the type of physical action that the target switching device should perform after receiving the operation instruction.

[0049] Optionally, the distribution network monitoring device extracts the switching action direction indicated in the operation instruction type corresponding to the target switching equipment. The switching action direction refers to the direction of state change required by the operation instruction for the target switching equipment, which is divided into two types: opening direction and closing direction. The opening direction refers to the direction in which the instruction requires the switching equipment to change from the current state to the opening state, and the closing direction refers to the direction in which the instruction requires the switching equipment to change from the current state to the closing state. This direction information is directly embedded in the instruction code of the operation instruction and is obtained by the distribution network monitoring device by parsing the instruction code.

[0050] Furthermore, the distribution network monitoring device retrieves the initial switching state of the target switchgear. The initial switching state refers to the stable open / closed state of the target switchgear before the fault occurred, which is divided into the closed state and the open state. The closed state refers to the state in which the moving and stationary contacts of the switchgear are in contact and can conduct current, while the open state refers to the state in which the moving and stationary contacts of the switchgear are separated and cannot conduct current.

[0051] Furthermore, the distribution network monitoring device matches the parsed switch action direction with the initial switch state to determine the type of physical action the target switchgear should perform after receiving the operation command. The physical action type refers to the type of mechanical movement of the moving contact relative to the stationary contact of the switchgear, categorized into three types: opening action, closing action, and no action. Specifically, when the switch action direction is opening and the initial switch state is closing, the physical action type is opening action; when the switch action direction is closing and the initial switch state is opening, the physical action type is closing action; when the switch action direction is consistent with the initial switch state (i.e., the opening direction corresponds to the initial opening state, and the closing direction corresponds to the initial closing state), the physical action type is no action.

[0052] In one embodiment, in the power outage simulation operation sequence associated with the fault event, the selected target power outage simulation operation is "to perform a tripping operation on the Chengdong No. 2 section switch of the 10 kV Chengdong line", and the corresponding target switching equipment is the Chengdong No. 2 section switch.

[0053] The power distribution network monitoring device analyzes the operation instruction code of the target power outage simulation operation and extracts the switch action direction indicated in the operation instruction type as the opening direction.

[0054] The distribution network monitoring device retrieves the initial switch state of the Chengdong No. 2 section switch, which was determined in step 10, as closed (moving and stationary contacts are in contact, and current is flowing). The distribution network monitoring device matches the opening direction with the initial closing state to determine that the physical action that the Chengdong No. 2 section switch should perform after receiving the operation command is an opening action (i.e., the moving contact separates from the stationary contact).

[0055] Step 202: Determine whether the target switching equipment has the mechanical feasibility conditions to perform the action based on the physical action type, and obtain the mechanical feasibility judgment result.

[0056] Optionally, the power distribution network monitoring device acquires the mechanical status parameters of the target switchgear. The mechanical status parameters refer to a set of parameters that reflect the integrity of the mechanical structure and the operating capability of the switchgear, including the energy storage status of the switch mechanism, the stroke margin of the moving contact, the oil pressure (hydraulic operating mechanism) or air pressure (pneumatic operating mechanism) of the operating mechanism, and the mechanical locking status, etc.

[0057] Optionally, the energy storage status of the switching mechanism refers to whether the energy storage of the operating mechanism of the switching equipment is sufficient. Sufficient energy means it has the capability to drive the action, while insufficient energy means it lacks the capability. The moving contact travel margin refers to the remaining travel distance required for the moving contact to complete the opening or closing action, and must be greater than or equal to the minimum travel threshold set by the factory of the switching equipment. The mechanical locking status refers to whether the switching equipment is in a mechanically locked state. A locked state means the action cannot be performed, while an unlocked state means the action can be performed. The above mechanical status parameters are acquired in real time by the distribution network monitoring device through mechanical status sensors deployed on the target switching equipment.

[0058] Furthermore, the distribution network monitoring device sets corresponding mechanical feasibility judgment criteria based on the physical action type of the target switchgear; if the physical action type is a tripping action, the judgment criteria are: sufficient energy storage in the switch mechanism, travel margin of the moving contact in the tripping direction ≥ minimum tripping travel threshold, and the mechanical locking state is unlocked.

[0059] If the physical action type is a closing action, the judgment criteria are: the switching mechanism has sufficient energy storage, the moving contact travel margin in the closing direction is ≥ the minimum closing travel threshold, and the mechanical locking state is unlocked.

[0060] If the physical action type is no action, the judgment criterion is: there is no need to meet the above requirements for energy storage, stroke margin and locking state, and mechanical feasibility is assumed to be met.

[0061] Furthermore, the distribution network monitoring device compares the mechanical state parameters of the target switchgear with the judgment criteria for the corresponding physical action type one by one. If all judgment conditions are met, the mechanical feasibility judgment result is "acceptable"; if at least one judgment condition is not met, the mechanical feasibility judgment result is "not acceptable".

[0062] In one embodiment, the physical action type of the target switchgear, the Chengdong No. 2 sectionalizing switch, is a tripping action. The mechanical status parameters collected by the mechanical status sensor on the switch are: sufficient energy storage in the switch mechanism (energy storage value is 95% of the rated energy storage), a 15 mm travel margin for the moving contact in the tripping direction (the minimum tripping travel threshold set by the factory for this switch is 10 mm), and the mechanical locking state is unlocked. The distribution network monitoring device sets the mechanical feasibility judgment criteria for the tripping action as: sufficient energy storage, tripping travel margin > 10 mm, and mechanical unlocking. Comparing the collected parameters with the judgment criteria, all three conditions are met; therefore, the distribution network monitoring device determines that the mechanical feasibility judgment result for the Chengdong No. 2 sectionalizing switch is met.

[0063] Step 203: Determine the initial expected switching state of the target switchgear based on the mechanical feasibility assessment results, and determine the constraint boundary of the initial expected switching state on the operation logic of adjacent switchgear based on the initial expected switching state and the electrical topology location information of the feeder segment to which the target switchgear belongs.

[0064] Optionally, the power distribution network monitoring device determines the initial expected switching state of the target switchgear based on the mechanical feasibility assessment result, as in steps 2031 to 2034.

[0065] Furthermore, the distribution network monitoring device acquires the electrical topology location information of the feeder segment to which the target switchgear belongs. A feeder segment refers to a line section in the distribution network formed by two adjacent switchgears; the feeder segment to which the target switchgear belongs is the line section located between the target switchgear and its two adjacent switchgears. The electrical topology location information refers to the relative position of the target switchgear within the entire distribution network electrical topology, including its connection to its two adjacent switchgears, the direction of power supply to its feeder segment, and the distribution information of the loads carried on the feeder segment. This information is retrieved by the distribution network monitoring device from the distribution network topology database, which stores the connection relationships and location information of all lines and equipment in the distribution network.

[0066] Furthermore, based on the initial expected switching state, the distribution network monitoring device analyzes the constraint boundaries of its operation logic on adjacent switching equipment. The constraint boundaries refer to the restrictive requirements imposed on the operation type and operation sequence of the target switching equipment when it is in the initial expected switching state, in order to ensure the power supply safety and topology stability of the distribution network.

[0067] Optionally, the specific analysis logic of this embodiment of the invention is as follows: if the initial expected switch state is the open state, then the adjacent switchgear must be constrained from performing a closing operation that may cause fault current to flow through the open section before the target switchgear completes the opening; if the initial expected switch state is the closed state, then the adjacent switchgear must be constrained from performing a opening operation that may cause a power supply loop to form in the closed section before the target switchgear completes the closing; if the initial expected switch state is the initial switch state (mechanically infeasible or no action), then there are no additional operational logic constraints on the adjacent switchgear, and the constraint boundary is unrestricted.

[0068] In one embodiment, the initial expected switching state of the switch is the open state. The electrical topology location information of the feeder segment to which the Chengdong No. 2 sectionalizing switch belongs is retrieved from the distribution network topology database: the adjacent switch to the left of this switch is the Chengdong No. 1 sectionalizing switch, and the adjacent switch to the right is the Chengdong No. 3 sectionalizing switch. The feeder segment belongs to the section between the No. 1 and No. 2 distribution transformers of the 10 kV Chengdong line. The power supply direction is from the Chengdong No. 1 sectionalizing switch to the Chengdong No. 2 sectionalizing switch, and the feeder segment carries an 80 ampere load from the No. 2 distribution transformer. Based on the initial expected switching state (open state), the constraint boundary is determined as follows: before the Chengdong No. 2 sectionalizing switch completes its opening action, the Chengdong No. 1 and No. 3 sectionalizing switches are prohibited from performing closing operations (to prevent fault current from flowing through the No. 1-No. 2 distribution transformer section or forming a reverse power supply loop).

[0069] Step 204: Determine the final expected switching state of the target switchgear based on the constraint boundaries.

[0070] Optionally, the distribution network monitoring device performs a comprehensive matching and verification between the constraint boundary and the overall power supply safety requirements of the distribution network, as well as the current operation plans of adjacent switching equipment. The overall power supply safety requirements of the distribution network refer to core requirements such as avoiding power supply loops, preventing the expansion of fault ranges, and ensuring power supply to important loads. The current operation plans of adjacent switching equipment refer to the operation arrangements of adjacent switching equipment preset by the distribution network monitoring device and executed concurrently with the target power outage simulation operation. Further, the distribution network monitoring device adaptively adjusts the initial expected switch state based on the matching and verification results (if there is no conflict between the constraint boundary and the power supply safety requirements and adjacent operation plans, the initial expected switch state is the final expected switch state; if there is a conflict, the initial expected switch state is adjusted to meet the constraint boundary and power supply safety requirements), determining the final expected switch state of the target switching equipment, as described in steps 2041 to 2043.

[0071] The embodiments of the present invention realize a comprehensive consideration from the action of a single device to the overall coordination of the distribution network, which makes the determination result of the final expected switch state accurate and reliable, ensures the rigor of the fault handling logic process, and thus improves the traceability and logical consistency of the fault handling process.

[0072] Optionally, the process of steps 2031 to 2034 includes:

[0073] Step 2031: If the mechanical feasibility assessment result is feasible, and the operation command type is a tripping command, and the initial switch state is a closed state, then the initial expected switch state is determined to change from a closed state to an open state.

[0074] Optionally, the mechanical feasibility assessment result is "feasible," meaning that the mechanical state parameters of the target switchgear meet the judgment criteria for the corresponding physical action type, and it possesses the mechanical capability to execute the actions required by the operation command. The operation command type is a tripping command, which is an operation command issued by the distribution network monitoring device to the target switchgear, requiring it to separate the moving contact from the stationary contact to cut off the current. The switch action direction embedded in the command code is the tripping direction. The initial switch state is a closed state, meaning that before the fault occurs, the moving and stationary contacts of the target switchgear are in a stable state of contact conduction current.

[0075] Therefore, when the distribution network monitoring device confirms that the above three conditions are met simultaneously, it indicates that the target switchgear has the mechanical basis to perform the tripping action, and the operation command matches the initial state (the initial closed state can perform the tripping action). Therefore, the initial expected switch state is determined to be the change from the closed state to the open state. The initial expected switch state refers to the expected state of the switchgear obtained only based on mechanical feasibility and the matching relationship between the command and the initial state, without considering the constraints of adjacent switchgear. The phrase "change from the closed state to the open state" clarifies the change process and final steady state of the switch state. That is, the final steady state is the open state. The open state refers to the stable state in which the moving and stationary contacts of the switchgear are completely separated and cannot conduct current.

[0076] In one embodiment, the selected target switchgear is the Chengdong No. 2 section switch. The distribution network monitoring device retrieves relevant data: Step 202 determines that the mechanical feasibility of the switch is feasible (the switch mechanism has sufficient energy storage, the moving contact travel margin in the opening direction is 15 mm > the minimum opening travel threshold of 10 mm, and the mechanical locking state is unlocked); the operation command type corresponding to the target power outage simulation operation associated in Step 20 is the opening command; the initial switch state determined in Step 10 is the closed state (moving and stationary contacts are in contact and conducting current).

[0077] The three conditions were verified and confirmed to be met. Therefore, the initial expected switch state of the Chengdong No. 2 section switch was determined to be the transition from the closed state to the open state, and its final steady state was the open state.

[0078] Step 2032: If the mechanical feasibility assessment result is feasible, and the operation command type is a closing command, and the initial switch state is open, then the initial expected switch state is determined to change from open to closed.

[0079] Optionally, the mechanical feasibility assessment result is feasible, consistent with step 2031. The operation command type is a closing command, which is an operation command issued by the distribution network monitoring device to the target switchgear, requiring it to make contact between the moving contact and the stationary contact to conduct current. The switch action direction embedded in the command code is the closing direction. The initial switch state is the open state, that is, before the fault occurs, the moving and stationary contacts of the target switchgear are in a stable state where they are separated and cannot conduct current.

[0080] Therefore, when the distribution network monitoring device confirms that all three conditions are met, it indicates that the mechanical state of the target switchgear supports the closing action, and the operation command matches the initial state (the initial open state can execute the closing action). Thus, the initial expected switch state is determined to be the transition from the open state to the closed state. The initial expected switch state here clarifies the state change trajectory and the final steady state. The final steady state is the closed state, which is the stable state of the contact current between the moving and stationary contacts.

[0081] In one embodiment, if the selected target power outage simulation operation is "to perform a closing operation on the Chengdong No. 3 section switch of the 10 kV Chengdong line", the corresponding target switchgear is the Chengdong No. 3 section switch. Data retrieval: Step 202 determines that the mechanical feasibility assessment result for this switch is feasible (sufficient energy storage in the switch mechanism, a moving contact travel margin of 12 mm in the closing direction > the minimum closing travel threshold of 8 mm, and the mechanical locking state is unlocked); the operation command type is a closing command; the initial switch state determined in step 10 is an open state (moving and stationary contacts separated, no current conduction). All three conditions are met; therefore, the initial expected switch state of the Chengdong No. 3 section switch is determined to be a transition from an open state to a closed state, with the final steady state being a closed state.

[0082] Step 2033: If the mechanical feasibility assessment result is infeasible, and the operation command type is a tripping command, and the initial switch state is open, then the initial expected switch state is determined to be open.

[0083] Optionally, if the mechanical feasibility assessment result is "infeasible," it means that the mechanical state parameters of the target switchgear do not meet the judgment criteria for the corresponding physical action type, and it does not have the mechanical capability to execute the actions required by the operation command. For example, the switch mechanism may have insufficient energy storage, the moving contact travel margin may be less than the minimum threshold, or it may be in a mechanically locked state. The operation command type is a tripping command, and the initial switch state is an open state, consistent with step 2032.

[0084] Therefore, when the above three conditions are confirmed, on the one hand, due to mechanical infeasibility, the target switching equipment cannot perform the action corresponding to the tripping command; on the other hand, the initial switch state is already in the tripping state, which is consistent with the target state required by the tripping command. Even if the action is performed, there will be no state change. Therefore, the initial expected switch state is determined to be the open state, that is, the initial switch state remains unchanged and there is no state transition process.

[0085] In one embodiment, if the target switchgear is the Chengdong No. 4 section switch, the distribution network monitoring device retrieves the data: Step 202 determines that the mechanical feasibility of the switch is not feasible (the energy storage of the switch mechanism is only 30% of the rated energy storage, which does not reach the 70% energy storage threshold required for the tripping action); the operation command type is the tripping command; the initial switch state determined in step 10 is the open state.

[0086] Since all three conditions are met, the initial expected switch state of the No. 4 section switch in the east of the city is determined to be the open state, and the initial state is maintained unchanged.

[0087] Step 2034: If the mechanical feasibility assessment result is infeasible, and the operation command type is a closing command, and the initial switch state is closed, then the initial expected switch state is determined to be closed.

[0088] Optionally, the mechanical feasibility assessment result is infeasible, consistent with step 2033. The operation command type is a closing command, consistent with step 2032. The initial switch state is closed, consistent with step 2031.

[0089] Therefore, when the distribution network monitoring device confirms that all three conditions are met, the target switchgear cannot perform the action corresponding to the closing command due to mechanical infeasibility. At the same time, the initial switch state is already in the closed state, which is consistent with the target state required by the closing command, and no state adjustment is required. Therefore, the distribution network monitoring device determines that the initial expected switch state is the closed state, that is, it keeps the initial switch state stable and there is no state transition process.

[0090] In one embodiment, if the target switchgear is the Chengdong No. 1 section switch, the distribution network monitoring device retrieves data: Step 202 determines that the mechanical feasibility judgment result of the switch is infeasible (it is in a mechanically locked state and cannot perform the closing action); the operation command type is a closing command; the initial switch state determined in step 10 is a closed state. All three conditions are met, therefore the initial expected switch state of the Chengdong No. 1 section switch is determined to be a closed state, and the initial state remains unchanged.

[0091] The embodiments of the present invention effectively avoid the deviation that may exist in single-dimensional judgment, so that the judgment result of the initial expected switching state has high accuracy and reliability, ensuring the rigor of the fault handling logic process, thereby improving the traceability and logical consistency of the fault handling process.

[0092] Optionally, the processes of steps 2041 to 2043 include:

[0093] Step 2041: Based on the constraint boundary, eliminate the branches of the simulation operation sequence that conflict with the initial expected switching state to obtain the effective simulation operation path.

[0094] Optionally, the power outage simulation operation sequence contains multiple parallel operation branches, each corresponding to a different combination of switching equipment operation schemes to cover different fault handling scenarios.

[0095] Optionally, the distribution network monitoring device compares each operation branch in the power outage simulation operation sequence with the constraint boundary, identifies conflicting branches, and denotes the remaining operation branches that meet the constraint boundary requirements as valid simulation operation paths. A conflict occurs when an operation branch contains operations of adjacent switching equipment that violate the restrictive requirements for adjacent switching equipment in the constraint boundary. For example, if the constraint boundary prohibits adjacent switching equipment from closing before the target switch is opened, and an operation branch contains closing operations of adjacent switches within that time period, then that branch is a conflicting branch. A valid simulation operation path refers to the set of switching operation schemes that can achieve the fault handling objective while satisfying the constraints of the target switching equipment.

[0096] In one embodiment, the target switching device is the Chengdong No. 2 sectionalizing switch, and the constraint boundary is: before the Chengdong No. 2 sectionalizing switch completes the opening action (the timing range is 0 to 5 seconds after the operation command is issued), the Chengdong No. 1 sectionalizing switch on the left and the Chengdong No. 3 sectionalizing switch on the right are prohibited from performing the closing operation.

[0097] The power distribution network monitoring device retrieves the power outage simulation operation sequence associated with the fault event. This sequence contains three operation branches: Branch 1 is "Chengdong No. 2 section switch opens (0-second command issued) → Chengdong No. 3 section switch closes (3-second command issued) → fault section isolation"; Branch 2 is "Chengdong No. 2 section switch opens (0-second command issued) → Chengdong No. 1 section switch remains closed → Chengdong No. 3 section switch remains open → fault section isolation"; Branch 3 is "Chengdong No. 2 section switch opens (0-second command issued) → Chengdong No. 1 section switch opens (4-second command issued) → fault section isolation".

[0098] The distribution network monitoring device compared the constraint boundary with the three branches: In branch one, the Chengdong No. 3 sectionalizing switch issued a closing command within 3 seconds, which falls within the 0-5 second time sequence prohibited by the constraint boundary, making it a conflicting branch; the operations of branches two and three did not violate the restrictive requirements of the constraint boundary. Therefore, the distribution network monitoring device excluded the conflicting branch one and determined branches two and three as valid simulated operation paths.

[0099] Step 2042: Based on the effective simulated operation path, the initial expected switch state is matched and verified with the bus power supply state in the real-time operation mode to obtain the matching and verification result. The matching and verification result is used to determine whether the initial expected switch state causes a reverse power supply anomaly.

[0100] Optionally, the distribution network monitoring device acquires the bus power supply status of the faulty line in real-time operation mode at the time of the fault occurrence. The bus power supply status refers to the power supply direction, voltage level, and power supply stability of the power supply bus connected to the faulty line. The power supply direction refers to the direction of current flow from the bus to the faulty line, the voltage level is the rated power supply voltage of the bus (such as 10 kV or 35 kV), and the power supply stability status refers to whether the bus is in a normal power supply state (no voltage drop, no power outage fault).

[0101] Furthermore, the distribution network monitoring device constructs matching verification rules, specifically as follows: it determines whether the power supply path direction corresponding to the initial expected switch state is consistent with the power supply direction in the bus power supply state, and whether it will cause the current to flow backward through the bus. Specifically, if the initial expected switch state is the open state, it is necessary to verify whether the current direction of the remaining power supply path after the open state is still consistent with the bus power supply direction; if the initial expected switch state is the closed state, it is necessary to verify whether the power supply path formed after the closed state has only a single current direction from the bus to the line, and no reverse current loop.

[0102] Furthermore, based on the aforementioned matching and verification rules, the distribution network monitoring device compares and verifies the initial expected switch state and bus power supply state corresponding to each valid simulated operation path one by one to obtain the matching and verification results. The matching and verification results are divided into two categories: one is no reverse power supply anomaly, that is, the power supply path direction corresponding to the initial expected switch state is consistent with the bus power supply direction, and no reverse current is generated; the other is reverse power supply anomaly, that is, the initial expected switch state causes the power supply path direction to be opposite to the bus power supply direction, forming an abnormal situation where reverse current flows through the bus.

[0103] In one embodiment, the effective simulated operation path is branch two and branch three, and the corresponding initial expected switch states are both Chengdong No. 2 section switch changing from closed to open (final steady state is open); the bus power supply status in the real-time operation mode is: the 10 kV Chengdong line to which Chengdong No. 2 section switch belongs is connected to the 10 kV bus of Chengdong substation, the bus power supply direction is from the bus to Chengdong No. 1 section switch and then to Chengdong No. 2 section switch, the voltage level is 10 kV, and the power supply stability status is normal.

[0104] The distribution network monitoring device establishes matching verification rules: when the Chengdong No. 2 section switch is in the open state, it verifies whether the current direction of the remaining power supply path (Chengdong bus → Chengdong No. 1 section switch → No. 1 distribution transformer area) is consistent with the power supply direction of the bus and whether there is no reverse current.

[0105] The distribution network monitoring device verifies the initial expected switch status and bus power supply status of Branch 2 and Branch 3: After the No. 2 section switch of East City in Branch 2 is opened, the No. 1 section switch of East City remains closed, and the current direction of the remaining power supply path is still bus → No. 1 section switch of East City → No. 1 distribution transformer area, which is consistent with the power supply direction of the bus; After the No. 2 section switch of East City in Branch 3 is opened, the No. 1 section switch of East City is tripped, and the remaining power supply path is only no-load on the bus side, with no current flow and no reverse current.

[0106] The distribution network monitoring device obtained the matching verification results: there was no reverse power supply abnormality in the initial expected switch states corresponding to branch 2 and branch 3.

[0107] Step 2043: If the initial expected switch state is determined to have no reverse power supply abnormality based on the matching verification result, then the initial expected switch state is determined as the final expected switch state of the target switch device.

[0108] Optionally, the distribution network monitoring device classifies and determines the initial expected switch state corresponding to each valid simulated operation path. The specific process is as follows:

[0109] If the matching verification result shows no reverse power supply anomaly, it means that the initial expected switch state meets the constraint boundary requirements and will not disrupt the normal power supply order of the bus. Therefore, the distribution network monitoring device directly determines the initial expected switch state as the final expected switch state of the target switch equipment. The final expected switch state refers to the final stable state that the target switch equipment should reach after comprehensive verification of all constraint conditions.

[0110] If the matching verification result indicates the presence of reverse power supply anomaly, it means that although the initial expected switch state meets the constraint boundary requirements, it will cause reverse current to flow through the bus, affecting power supply safety. In this case, the distribution network monitoring device needs to adjust and optimize the initial expected switch state. The adjustment and optimization logic is as follows: based on the bus power supply status and effective simulated operation path, redetermine the switch state that can avoid reverse power supply anomaly, and prioritize the state with the smallest difference from the initial expected switch state (e.g., if the initial expectation is a closed state, adjust to a kept open state; if the initial expectation is an open state, adjust to a delayed open state until the adjacent power supply path is cut off); determine the adjusted and optimized switch state as the final expected switch state of the target switchgear.

[0111] In one embodiment, the matching verification results corresponding to the effective simulated operation path branch two and branch three are both without reverse power supply abnormality. Therefore, the initial expected switch state (the Chengdong No. 2 section switch changes from closed to open) is directly determined as the final expected switch state of the target switchgear.

[0112] In another embodiment, the target switching device is the Chengxi No. 3 section switch of the 10 kV Chengxi line. The initial expected switch state corresponding to the effective simulated operation path is the closed state. The matching verification result is that there is a reverse power supply abnormality (after closing, a reverse current will be formed from the adjacent line bus to the Chengxi line bus).

[0113] Based on the power supply status of the Chengxi Line bus (power supply direction is bus → Chengxi Line, voltage level 10 kV) and the effective simulated operation path, the distribution network monitoring device adjusts the initial expected switch status, changing the closed status to the open status (minimizing the difference from the initial expected status), and records the reasons for the adjustment (to avoid reverse power supply anomalies) and the basis (matching verification results, bus power supply direction data); finally, the adjusted open status is determined as the final expected switch status of the Chengxi No. 3 section switch.

[0114] The embodiments of the present invention ensure the matching between the final expected switching state and the operation instructions and mechanical feasibility, and also ensure its adaptation to the overall power supply topology and safety requirements of the distribution network, thereby improving the rigor of fault handling analysis and thus enhancing the traceability and logical consistency of the fault handling process.

[0115] Optionally, the process of steps 301 to 302 includes:

[0116] Step 301: Based on the final expected switching state of each automated switchgear and the remote signaling change information and remote control execution feedback information in the actual action information, a state consistency judgment is performed to obtain the state consistency result between the actual final switching state and the final expected switching state. The remote signaling change information includes the time of occurrence of the remote signaling change, the switching state before the change, and the switching state after the change.

[0117] Optionally, for each automated switchgear, the distribution network monitoring device retrieves the final expected switch state of the device during the corresponding power outage simulation operation, as well as the remote signaling change information and remote control execution feedback information from the actual action information of the automated switchgear within the fault event time window. Remote signaling change information refers to the information about the state of the automated switchgear changing from one stable state to another, specifically including the time of occurrence of the remote signaling change, the switch state before the change, and the switch state after the change.

[0118] Optionally, the occurrence time of remote signaling change refers to the specific point in time (accurate to the second) at which the switch state begins to change; the switch state before change refers to the stable state (closed or open) before the change; and the switch state after change refers to the stable state (closed or open) after the change. Remote control execution feedback information refers to the result feedback information after the automated switchgear receives and executes the remote control command from the distribution network monitoring device, including execution success and execution failure. Execution success indicates that the equipment has completed the corresponding opening and closing action according to the command; execution failure indicates that the equipment has not completed the opening and closing action according to the command (e.g., no action, incomplete action, etc.).

[0119] Optionally, the distribution network monitoring device constructs a state consistency judgment rule. The specific judgment logic is as follows: First, verify the remote control execution feedback information. If the execution fails, the state consistency result is directly determined to be inconsistent; if the execution is successful, proceed to the second step of judgment. Second, extract the switch state after the change in the remote signaling change information and compare it with the final expected switch state. If the two are consistent (both are closed or both are open), the state consistency result is consistent; if the two are inconsistent (one is closed and the other is open), the state consistency result is inconsistent. Based on the above rules, the state consistency judgment is performed sequentially for each automated switchgear to obtain the corresponding device's state consistency result, including consistent and inconsistent results.

[0120] In one embodiment, the faulty line is the 10 kV Chengdong line, and the fault event time window is set to within 30 minutes after the fault occurs (14:30:00) (i.e., from 14:30:00 to 15:00:00). The automated switching equipment on this line includes Chengdong No.1 section switch, Chengdong No.2 section switch, Chengdong No.3 section switch, and Chengdong No.4 section switch. The following description takes Chengdong No.2 section switch and Chengdong No.4 section switch as examples.

[0121] For the Chengdong No. 2 section switch: the distribution network monitoring device retrieves its final expected switch state as open; it obtains its actual action information within the fault event time window, including the remote signaling change information: the remote signaling change occurred at 14:30:03, the switch was closed before the change, and the switch was open after the change; the remote control execution feedback information is successful. Verification is performed according to the state consistency judgment rules: First, the remote control execution feedback information is successful, proceeding to the second step; second, the switch state after the change in the remote signaling change information is open, consistent with the final expected switch state (open). Therefore, the state consistency result of the Chengdong No. 2 section switch is determined to be consistent.

[0122] For the Chengdong No. 4 section switch: its expected final switch state is retrieved as open; its actual action information within the fault event time window is obtained, and the remote signaling change information is as follows: no remote signaling change occurred at the time of the change (no remote signaling change occurred), no switch state before the change, and no switch state after the change; the remote control execution feedback information is execution failure (equipment did not operate). Based on the state consistency judgment rule: the remote control execution feedback information is execution failure, therefore the state consistency result of the Chengdong No. 4 section switch is determined to be inconsistent.

[0123] Step 302: Based on the state consistency results, combined with the remote signaling status of the automated switchgear within the event time window, whether there is a remote signaling change event in the actual action information, and the remote signaling change direction of the remote signaling change event, determine the action anomaly judgment result.

[0124] Optionally, remote signaling status refers to the real-time state sequence of the switchgear within the fault event time window (including the stable state at each time point). The existence of a remote signaling change event refers to whether the equipment has undergone a remote signaling change within the time window (yes or no). The direction of the remote signaling change refers to the direction of change of the switch state from closed to open or from open to closed. Therefore, the distribution network monitoring device uses the state consistency result as the judgment criterion, combined with the stability of the remote signaling status, the presence or absence of a remote signaling change event, and the matching of the remote signaling change direction with the expected action direction, to comprehensively judge each automated switchgear and obtain the action anomaly judgment result, as detailed in steps 3021 to 3024.

[0125] The embodiments of the present invention can accurately identify abnormal actions of automated switching equipment during fault handling, ensuring the pertinence and effectiveness of fault handling solutions, thereby improving the traceability and logical consistency of the fault handling process.

[0126] Optionally, the process of steps 3021 to 3024 includes:

[0127] Step 3021: If the state consistency result is inconsistent, and there is no remote signaling change event in the actual action information, and the remote signaling state of the automated switchgear remains the same as the initial switch state and opposite to the final expected switch state within the event time window, then determine whether a remote control command corresponding to the final expected switch state was issued to the automated switchgear within the fault event time window, and whether the communication link between the automated switchgear and the master station is normal within the response time interval from the time the remote control command was issued to the end of the preset maximum response time limit thereafter. If a remote control command was issued and the communication link is normal within the response time interval, then the action anomaly judgment result is determined to be refusal to operate.

[0128] Optionally, a state consistency result of "state inconsistency" means that the actual final switching state of the automated switchgear does not match the expected final switching state of the steps. The absence of remote signaling change events in the actual action information means that the automated switchgear did not undergo any change in switching state from one stable state to another within the fault event time window, and there is no valid data in the remote signaling change information regarding the occurrence time, the switch state before the change, and the switch state after the change.

[0129] Optionally, maintaining the remote signaling state as the same as the initial switching state and opposite to the final expected switching state means that the real-time state of the device remains the same as the initial switching state throughout the entire time window, and the initial switching state and the final expected switching state are opposite to each other. For example, if it is initially closed, it is expected to be open, and if it is initially open, it is expected to be closed.

[0130] Therefore, when the distribution network monitoring device confirms that all the above-mentioned pre-judgment conditions are met, it confirms whether a remote control command corresponding to the final expected switch state has been issued to the automated switch equipment within the fault event time window. The remote control command corresponding to the final expected switch state refers to the operation command that enables the equipment to reach the final expected switch state (if the final expected state is open, it corresponds to the tripping command; if the final expected state is closed, it corresponds to the closing command). It also confirms whether the communication link between the automated switch equipment and the master station is normal within the response time interval from the time the remote control command is issued until the end of the preset maximum response time limit thereafter. Among them, the preset maximum response time limit refers to the maximum time that the distribution network monitoring device should complete the action and feedback the result after receiving the remote control command, which is preset according to the type of automated switchgear and communication method. It is generally set to 5 to 10 seconds. The response time interval is the time range from the moment the remote control command is issued to the preset maximum response time limit. The communication link status refers to the working status of the communication channel between the device and the master station used to transmit instructions and status information, including normal and abnormal. The normal status means that the communication channel is unobstructed and can transmit data stably without packet loss or interruption. The abnormal status means that the communication channel has packet loss, excessive latency or interruption, and cannot transmit data normally.

[0131] If it is confirmed that the corresponding remote control command was indeed issued within the fault event time window, and the communication link between the device and the master station is normal within the response time interval, it means that the device failed to complete the state transition as instructed when it had the conditions to receive and execute commands. Therefore, the abnormal action judgment result is determined to be a refusal to operate.

[0132] Step 3022: If the state consistency result is inconsistent, and there is a remote signaling change event in the actual action information, and the direction of the remote signaling change event is opposite to the direction of the final expected switch state, then determine whether there is an interlocking action signal within the fault event time window. If there is an interlocking action signal, and the direction of the remote signaling change is not related to any control command, then determine the action anomaly judgment result as a false operation.

[0133] Optionally, the state consistency result is consistent with step 3021 for inconsistent states. The actual action information includes remote signaling change events, which refer to changes in the switch state of the automated switchgear from one stable state to another within the fault event time window. The remote signaling change information contains valid data on the occurrence time, the switch state before the change, and the switch state after the change. The remote signaling change direction of the remote signaling change event is opposite to the direction of the final expected switch state; that is, the actual remote signaling change direction is inconsistent with the required direction (e.g., the required direction is the opening direction, but the actual direction is the closing direction).

[0134] Therefore, when all the pre-defined judgment conditions are met, it is determined whether an interlocking action signal exists within the fault event time window. An interlocking action signal refers to a linkage signal in the distribution network system triggered by changes in the status of other equipment or specific fault conditions, used to control the operation of this automated switching equipment. This signal is not a remote control command directly issued by the distribution network monitoring device, but rather a preset linkage control signal from the system.

[0135] If the distribution network monitoring device confirms the existence of an interlocking action signal, it confirms that the remote signal change direction is not related to any control command (including remote control command and other active control command) issued by the distribution network monitoring device. That is, the remote signal change of the equipment is not triggered by the control command issued by the master station, but by the interlocking action signal and the change direction is opposite to the expected direction. Therefore, the abnormal action judgment result is determined to be a false action.

[0136] Step 3023: If the state consistency result is consistent, and a remote signaling change event exists in the actual action information, and the direction of the remote signaling change event is consistent with the direction of the final expected switch state, then determine whether the occurrence time of the remote signaling change is within the response time interval from the time the remote control command is issued to the end of the preset maximum response time limit thereafter. If the occurrence time of the remote signaling change is within the response time interval, then determine that the action anomaly judgment result is no action anomaly.

[0137] Optionally, the state consistency result is state consistency, which means that the actual final switching state of the automated switchgear is consistent with the final expected switching state; the actual action information contains a remote signaling change event consistent with step 3022; the remote signaling change direction of the remote signaling change event is consistent with the direction of the final expected switching state, which means that the actual state change direction of the equipment is the same as the change direction required to achieve the final expected switching state (e.g., if the required direction is the opening direction, the actual direction is also the opening direction).

[0138] When all the pre-conditions are met, determine whether the occurrence time of the remote signaling change is within the response time interval from the time the remote control command is issued to the end of the preset maximum response time limit thereafter. The occurrence time of the remote signaling change refers to the specific time point at which the switch state begins to change; the time the remote control command is issued, the preset maximum response time limit, and the response time interval are consistent with step 3021.

[0139] If the distribution network monitoring device confirms that the occurrence of the remote signal change is within the above-mentioned response time interval, it means that after the main station issues the remote control command, the device completes the state change in the expected direction within the specified response time, and the final state is consistent with the expectation. Therefore, the abnormal action judgment result is determined to be no abnormal action.

[0140] Step 3024: If the state consistency result is consistent, and there is no remote signaling change event in the actual action information, and the remote signaling state of the automated switchgear within the event time window remains the same as the final expected switch state, then the action anomaly determination result is determined to be no action anomaly.

[0141] Optionally, the state consistency result is that the state is consistent with step 3023; there is no remote signaling change event in the actual action information, which is consistent with step 3021; ​​the remote signaling state of the automated switchgear is maintained in the same way as the final expected switch state within the event time window, which means that the real-time state sequence of the equipment is always maintained in the final expected switch state throughout the entire fault event time window, and no state change occurs.

[0142] Therefore, when all the pre-judgment conditions are met, it means that the equipment can reach the final expected switching state without any state change, and the expected state is indeed maintained throughout the entire fault handling process without any unexpected state changes. Therefore, the distribution network monitoring device determines the abnormal action judgment result as no abnormal action.

[0143] The embodiments of the present invention construct a full-scenario system covering failure to operate, maloperation, and no operation, which can accurately identify the operation status of automated switchgear during fault handling, improve the pertinence and reliability of fault handling solutions, and thus enhance the traceability and logical consistency of the fault handling process.

[0144] Optionally, the processes of steps 401 to 404 include:

[0145] Step 401: Based on the power distribution network topology corresponding to the power supply impact range after the operation and the automatic switchgear whose action anomaly judgment result is failure to operate, identify the boundary automatic switchgear that is actually in the open state but is currently in the closed state due to failure to operate.

[0146] Optionally, the distribution network monitoring device retrieves the distribution network topology corresponding to the power supply impact area after the operation, and extracts the automated switching equipment whose action anomaly judgment result is "refusal to operate". The distribution network topology refers to the connection relationships and relative location information of all lines, automated switching equipment, distribution transformers, and other equipment within this range, including the connection paths of each feeder segment, the distribution nodes of the switching equipment, and the connection location of the distribution transformer.

[0147] Optionally, for automated switchgear that fails to operate, the distribution network monitoring device retrieves its final expected switch status and actual switch status. The actual switch status refers to the equipment's true stable state within the fault event time window. Further, based on the aforementioned distribution network topology, the distribution network monitoring device traverses all automated switchgear that fails to operate, filtering out equipment whose actual state differs from its intended state due to failure to operate. The specific filtering logic is as follows: it determines whether the final expected switch status of the refusing-operation equipment is open, and whether the actual switch status is closed. Here, "intended state" refers to the final expected switch status. Because the refusing-operation equipment did not execute the trip command, it remains in a closed state. This closed state prevents the effective isolation of fault areas or power outage areas that should have been isolated, thus affecting the accuracy of the power supply impact range.

[0148] Furthermore, the distribution network monitoring device identifies the screened equipment as boundary automated switching equipment. Boundary automated switching equipment refers to automated switching equipment located at the boundary of the power supply influence range after operation, and whose actual state is opposite to the expected state (expected to be open, actual to be closed) due to failure to operate, thereby affecting the definition of the power supply range. This type of equipment is a key node in dividing the actual power supply area and the fault outage area, and its abnormal state directly leads to a deviation in the power supply influence range.

[0149] In one embodiment, the power supply impact range after the operation is the section between distribution substations No. 2 and No. 3 of the 10 kV Chengdong line (expected to be isolated and de-energized due to the tripping of Chengdong No. 2 sectionalizing switch). The distribution network topology is as follows: Chengdong No. 1 sectionalizing switch → No. 1 distribution substation → Chengdong No. 2 sectionalizing switch → No. 2 distribution substation → Chengdong No. 3 sectionalizing switch → No. 3 distribution substation → Chengdong No. 4 sectionalizing switch. Each distribution substation is connected to the main line through its corresponding sectionalizing switch. The automated switching device that failed to operate according to the abnormal operation judgment result is Chengdong No. 4 sectionalizing switch. Its expected final switch state is open (the tripping command needs to be executed to isolate the non-faulty area at the end), but the actual switch state is closed (the tripping command was not executed due to failure to operate). Chengdong No. 3 sectionalizing switch is also a device that failed to operate. Its expected final switch state is open, but the actual switch state is closed.

[0150] The distribution network monitoring device scanned all the aforementioned devices that refused to operate and, based on the distribution network topology, determined that: the Chengdong No. 3 sectionalizing switch is located at the boundary of the power supply impact area (the section between distribution substations No. 2 and No. 3) after operation. Because it refused to operate, it was actually in a closed state (intentionally open), meaning that distribution substation No. 3, which should have been included in the power outage area, was not isolated; the Chengdong No. 4 sectionalizing switch is located at the end of the line, and although it refused to operate, it was not at the boundary of the power supply impact area. Therefore, the distribution network monitoring device identified the Chengdong No. 3 sectionalizing switch as a boundary automation switching device.

[0151] Step 402: Based on the identification and operation of the boundary automation switchgear, the adjacent non-faulty feeder segments that are electrically connected to the power supply impact range are identified, and the distribution transformers connected to the adjacent non-faulty feeder segments are identified as priority power supply restoration targets that were mistakenly included in the power outage range due to failure to operate.

[0152] Optionally, the distribution network monitoring device uses the boundary automated switchgear as the core node, retrieves the distribution network topology, and analyzes the port connection relationship of the boundary automated switchgear. The port connection relationship refers to the information such as feeder segments and equipment connected to the input and output ports of the switchgear, including faulty or non-faulty feeder segments connected on the left, feeder segments and distribution equipment connected on the right, etc.

[0153] Furthermore, based on port connection relationships, the distribution network monitoring device identifies adjacent non-faulty feeder segments that are electrically connected to the power supply impact range after the operation. Here, an adjacent non-faulty feeder segment refers to a feeder segment that is adjacent to the power supply impact range after the operation, and that has not experienced a fault and is in a normal power supply state. Electrical connection means that a current conduction path is directly formed through closed switching equipment or lines. That is, a conduction relationship is formed between the adjacent non-faulty feeder segment and the power supply impact range after the operation through boundary automated switching equipment (actually closed state).

[0154] Furthermore, the distribution network monitoring device traverses the identified adjacent non-faulty feeder sections and extracts all distribution transformers connected to those feeder sections. Due to the failure of the boundary automation switchgear to operate, these distribution transformers, which should not have been affected by the power supply after the operation, are mistakenly included in the power outage area (due to power loss caused by electrical connection with the power outage area). The aforementioned distribution transformers that were mistakenly included in the power outage area are identified as priority power restoration targets due to failure to operate. Therefore, priority power restoration targets refer to equipment that needs to have its power restored first during the fault handling process. Their priority is higher than that of ordinary power loss equipment because the power loss of such equipment is not due to its own or the feeder section's fault, but rather a secondary power loss caused by the failure of the switch to operate.

[0155] In one embodiment, the boundary automation switchgear is the Chengdong No. 3 section switch, and its port connection relationship is as follows: the left input port is connected to the power supply influence range after the operation (the section of distribution transformer area No. 2-3, the fault-related area), and the right output port is connected to the feeder section (non-fault feeder section) where distribution transformer area No. 3 is located and the feeder section (non-fault feeder section) where distribution transformer area No. 4 is located.

[0156] Based on port connection relationship analysis, the power distribution monitoring device identified the adjacent non-faulted feeder segments that were electrically connected to the power supply impact range after the operation as the feeder segments of distribution substation No. 3 and distribution substation No. 4 (electrical connection was formed because the No. 3 section switch in the east of the city was actually closed).

[0157] The distribution network monitoring device identified two adjacent non-faulty feeder sections connected to distribution transformers: transformer No. 3 in distribution substation No. 3 and transformer No. 4 in distribution substation No. 4. Due to the failure of the No. 3 sectionalizing switch in the eastern part of the city to operate, these two distribution transformers were incorrectly included in the power outage area. Therefore, the distribution network monitoring device identified transformers No. 3 and No. 4 as priority targets for power restoration due to their failure to operate.

[0158] Step 403: Based on the abnormal action judgment result of the automated switchgear that was malfunctioned and the power supply branch that was mistakenly disconnected due to malfunction in the power supply influence range after the operation, the isolated non-faulty power supply island is identified, and the distribution transformer associated with the isolated non-faulty power supply island is identified as the object for recovery of secondary power loss due to malfunction.

[0159] Optionally, the distribution network monitoring device retrieves the automated switching equipment whose abnormal operation judgment result indicates malfunction, and simultaneously retrieves the remote signaling change information of the malfunctioning equipment, including the time of occurrence of the remote signaling change, the switch status before the change, the switch status after the change, and the direction of the remote signaling change, to clarify the actual impact of the malfunctioning equipment's action on the power supply path. Based on the power supply impact range after the operation, the device locates the power supply branch that was incorrectly disconnected due to the malfunctioning equipment. Here, a power supply branch refers to the specific power supply path in the distribution network from the power source to the distribution transformer, consisting of lines and switching equipment connected in series; an incorrectly disconnected power supply branch refers to a branch that was in a non-faulty state and should not have been disconnected, but was cut off due to the malfunctioning tripping action of the automated switching equipment, resulting in power loss for the equipment within the branch.

[0160] Furthermore, based on the aforementioned erroneously disconnected power supply branches, the distribution network monitoring device analyzes the distribution network topology and identifies isolated non-faulty power supply islands. These isolated non-faulty power supply islands refer to independent power supply areas formed by the erroneous disconnection of power supply branches due to equipment malfunction, resulting in the isolation of non-faulty areas that were originally connected to the main power grid system. The equipment in these areas are all non-faulty, but they lose power because the power supply path has been erroneously cut off, and they cannot obtain power through other paths.

[0161] Furthermore, the distribution network monitoring device traverses the identified isolated non-faulty power supply islands and extracts all associated distribution transformers within the power supply island. These distribution transformers experience secondary power loss due to the formation of isolated non-faulty power supply islands, meaning the cause of the power loss is not their own fault or the fault in the area, but rather a chain of power loss caused by the malfunction of other switching equipment. These distribution transformers are identified as objects for restoration of secondary power loss due to malfunction, and these objects are the equipment that needs to be prioritized for power restoration during fault handling.

[0162] In one embodiment, the automated switchgear whose abnormal operation was determined to be a false trip was the Chengdong No. 1 section switch. Its remote signaling change information was as follows: the time of the remote signaling change was 14:30:05, the switch was closed before the change, the switch was open after the change, and the direction of the remote signaling change was the opening direction (the switch was expected to be closed in the final expected state, and there was no opening command, which is a false trip).

[0163] Based on the analysis of the power supply impact range after the operation, the distribution network monitoring device determined that after the erroneous tripping of the Chengdong No. 1 sectionalizing switch, the incorrectly disconnected power supply branch was the power supply branch from the Chengdong substation busbar to the No. 1 distribution transformer area (this branch was not faulty). Further analysis of the distribution network topology revealed that after this branch was disconnected, the area where the No. 1 distribution transformer area was located was isolated from the main power grid, forming an isolated non-faulty power supply island (the area contained only the No. 1 distribution transformer area, with no other power supply paths). The distribution transformer associated with this isolated non-faulty power supply island was identified as the No. 1 distribution transformer of the No. 1 distribution transformer area, which suffered secondary power loss due to the erroneous tripping of the Chengdong No. 1 sectionalizing switch. Therefore, the distribution network monitoring device identified the No. 1 distribution transformer as the target for restoration after the secondary power loss caused by the erroneous tripping.

[0164] Step 404: Based on the priority power supply objects, the objects to be restored due to malfunction and secondary power loss, and the automated switching equipment whose action abnormality judgment result is no action abnormality, generate a fault handling logic flow.

[0165] Optionally, the distribution network monitoring device generates a fault handling logic flow based on the priority power supply objects, the objects to be restored due to malfunction and secondary power loss, and the automated switching equipment whose action abnormality judgment result is no action abnormality, as in steps 4041 to 4044.

[0166] This invention takes into account the impact of abnormal operation of switching equipment on the power supply range, and realizes the process from abnormal node location to recovery object identification and then to handling process generation. This makes the generated fault handling logic process targeted and operable, thereby improving the traceability and logical consistency of the fault handling process.

[0167] Optionally, the processes of steps 4041 to 4044 include:

[0168] Step 4041: Taking the emergency distribution transformer as the priority power supply restoration target and the secondary power loss restoration target caused by malfunction, traverse the backup feeder path in the global topology of the distribution network that is connected to the emergency distribution transformer by a tie switch and is in an available state. Based on the backup feeder path and the automated switching equipment outside the power supply impact range after the operation that is not affected by the abnormal operation, determine the remote control operation sequence for switching the emergency distribution transformer to backup feeder power supply.

[0169] Optionally, the global topology of the distribution network refers to the complete connection relationship and location information of all feeder segments, switching equipment, distribution transformers, tie switches and other equipment in the entire distribution network, which is different from the local topology corresponding to the power supply impact range after the operation, and covers the entire power supply structure of both fault areas and non-fault areas.

[0170] A tie switch is a switching device used to connect different feeder sections to achieve load transfer or backup power supply, and has the function of connecting different power supply paths.

[0171] Optionally, the distribution network monitoring device prioritizes the emergency distribution transformer as the object to be restored and the object to be restored after secondary power loss due to malfunction. Each emergency distribution transformer is used as an independent query unit. The device traverses the entire distribution network topology to filter out backup feeder paths that are connected to the emergency distribution transformer via tie switches and are in an available state. An available backup feeder path refers to a feeder segment on the path that is fault-free, has a line current-carrying capacity sufficient for the emergency distribution transformer's load requirements, and whose basic switching equipment (non-abnormal equipment) is in normal operating condition and capable of handling the transferred load. The filtering logic in this embodiment is as follows: first, locate the current feeder segment where the emergency distribution transformer is located; then, query other feeder segments through tie switches to determine whether the associated feeder segment is a non-faulty feeder (not included in the power supply impact range after the operation), and whether the path from the feeder segment to the emergency distribution transformer is complete and whether the current-carrying capacity matches.

[0172] Furthermore, the distribution network monitoring device retrieves automated switchgear outside the power supply impact range after the operation that has not been affected by abnormal operation. Among them, automated switchgear unaffected by abnormal operation refers to automated switchgear whose abnormal operation judgment result is no abnormal operation, or which has not been included in the relevant operation sequence for this fault handling, and whose own operating status is normal. In conjunction with the selected backup feeder path, a remote control operation sequence for switching the emergency distribution transformer to the backup feeder power supply is planned and determined. Among them, the remote control operation sequence refers to the set of steps in which the distribution network monitoring device issues opening and closing commands to the relevant switchgear on the path in sequence through remote control. The operation object, operation type (opening or closing), and operation sequence must be clearly defined to ensure that a complete power supply path from the backup feeder to the emergency distribution transformer can be formed after the operation, while cutting off the original fault-related power supply path.

[0173] In one embodiment, the priority targets for power restoration are distribution transformer No. 3 and distribution transformer No. 4, and the target for restoration after secondary power loss due to accidental operation is distribution transformer No. 1. All three are emergency distribution transformers. The power supply impact range after the operation is the section between distribution transformer No. 2 and No. 3 of the 10 kV Chengdong line.

[0174] The distribution network monitoring device retrieves the global topology of the distribution network and shows that: the Chengdong Line feeder section 3-4, where distribution transformers No. 3 and No. 4 are located, is connected to the 10kV Chengxi Line (a non-faulty feeder with a current carrying capacity of 300 amps, meeting the combined load demand of 230 amps for distribution transformers No. 3 and No. 4) via tie switch No. 1, and tie switch No. 1 is in an available state; the Chengdong Line feeder section 1, where distribution transformer No. 1 is located, is connected to the 10kV Chengbei Line (a non-faulty feeder with a current carrying capacity of 250 amps, meeting the load demand of 120 amps for distribution transformer No. 1) via tie switch No. 2, and tie switch No. 2 is in an available state.

[0175] The distribution network monitoring device retrieves automated switchgear outside the power supply impact range after the operation that was not affected by abnormal operation, including the No. 1 section switch of the Chengxi Line and the No. 1 section switch of the Chengbei Line (both of which are equipment without abnormal operation); combined with the backup feeder path (Chengxi Line → Tie Switch No. 1 → Chengdong Line No. 3-4 feeder section, Chengbei Line → Tie Switch No. 2 → Chengdong Line No. 1 feeder section), the remote control operation sequence is determined as follows: Sequence 1 (for distribution transformers No. 3 and No. 4) is "Chengxi Line No. 1 section switch closed → Tie Switch No. 1 closed → Chengdong Line No. 3 section switch opened (cutting off the original fault path)"; Sequence 2 (for distribution transformer No. 1) is "Chengbei Line No. 1 section switch closed → Tie Switch No. 2 closed → Chengdong Line No. 1 section switch opened (cutting off the power loss path caused by erroneous operation)".

[0176] Step 4042: Based on the remote control operation sequence and the automatic switching equipment with no abnormal operation result, exclude uncontrollable equipment due to communication interruption or remote control function lockout, obtain the remote control operation instruction set, and determine the first stage load transfer control process based on the remote control operation instruction set.

[0177] Optionally, for each automated switchgear corresponding to each operation command in each remote control operation sequence, the distribution network monitoring device determines whether the communication link between the device and the distribution network monitoring device is normal, and whether the remote control function of the device is unlocked. The communication link status refers to the working status of the channel used to transmit remote control commands and status feedback information. A normal state is a smooth channel with no packet loss or interruption; an abnormal state is packet loss, excessive latency, or interruption. Remote control function lockout means that the device is prohibited from receiving remote control commands due to local faults, protection actions, or manual settings. An unlocked state allows the receiving and execution of remote commands. Further, the distribution network monitoring device excludes uncontrollable devices in the remote control operation sequence that have communication interruptions or remote control function lockouts. For operation sequences that remain complete after excluding uncontrollable devices, the operation commands corresponding to the controllable devices are extracted to obtain a remote control operation command set. The remote control operation command set refers to a collection containing all remotely executable opening and closing commands, with each command clearly specifying the operation object, operation type, and operation sequence.

[0178] Furthermore, based on the remote control operation command set, the distribution network monitoring device obtains the first-stage load transfer control process according to the sequence of operations and the correlation of the operated objects. The first-stage load transfer control process refers to the operation process for rapidly transferring load to the emergency distribution transformer through a controllable backup feeder path. The core objective is to restore the power supply of the emergency distribution transformer in the shortest possible time, and it has the highest priority.

[0179] In one embodiment, the first remote control operation sequence is "closing the No. 1 section switch of the Chengxi Line → closing the No. 1 tie switch → opening the No. 3 section switch of the Chengdong Line," and the second sequence is "closing the No. 1 section switch of the Chengbei Line → closing the No. 2 tie switch → opening the No. 1 section switch of the Chengdong Line." The automated switchgear without operational abnormalities includes the No. 1 section switch of the Chengxi Line, tie switch 1, the No. 1 section switch of the Chengbei Line, and tie switch 2. The No. 3 section switch of the Chengdong Line is a non-operational abnormality device (already ruled out), and the No. 1 section switch of the Chengdong Line is a maloperational abnormality device (already ruled out). Controllability is confirmed: the No. 1 section switch of the Chengxi Line has normal communication and is remotely unlocked; tie switch 1 has normal communication and is remotely unlocked; the No. 1 section switch of the Chengbei Line has normal communication and is remotely unlocked; tie switch 2 has normal communication and is remotely unlocked; there are no uncontrollable devices.

[0180] The integrated remote control operation command set is as follows: Command 1 "Close the No. 1 section switch of the West City Line", Command 2 "Close the No. 1 connecting switch", Command 3 "Open the No. 3 section switch of the East City Line" (discarded due to equipment malfunction), Command 4 "Close the No. 1 section switch of the North City Line", Command 5 "Close the No. 2 connecting switch", Command 6 "Open the No. 1 section switch of the East City Line" (discarded due to equipment malfunction); The revised command set is Command 1, 2, 4, and 5.

[0181] The first phase of load transfer control process is formed based on the revised instruction set: "Step 1: Control the closing of the No. 1 section switch of the Chengxi line; Step 2: Control the closing of the No. 1 tie switch (to complete the connection of the backup paths of the No. 3 and No. 4 distribution transformers); Step 3: Control the closing of the No. 1 section switch of the Chengbei line; Step 4: Control the closing of the No. 2 tie switch (to complete the connection of the backup path of the No. 1 distribution transformer)."

[0182] Step 4043: Based on the updated power supply status after the execution of the first-stage load transfer control process and the remaining distribution transformers that have not been restored to power supply within the power supply impact range after the operation, select the suboptimal backup path with multi-level interconnection transfer conditions, and generate the second-stage progressive load restoration control process based on the suboptimal backup path and its corresponding automated switching equipment.

[0183] Optionally, the distribution network monitoring device simulates the execution of the first-stage load transfer control process, or obtains the updated power supply status after the actual execution of the process. The updated power supply status refers to comprehensive information such as the power supply status (power restored or still de-energized) of each distribution transformer in the distribution network, the load distribution of each feeder section, and the actual status of switching equipment after the execution of the first-stage operation. Based on the updated power supply status, the distribution network monitoring device filters out the remaining distribution transformers within this range that have not yet had their power restored. The remaining distribution transformers that have not yet had their power restored refer to equipment that failed to have its power restored through the first-stage load transfer process due to reasons such as the unavailability of the backup feeder path in the first stage, excessive load, or the presence of uncontrollable equipment along the path. The restoration priority of such equipment is lower than that of emergency distribution transformers.

[0184] Furthermore, for each remaining distribution transformer without restored power, the distribution network monitoring device traverses the entire distribution network topology to screen for suboptimal backup paths with multi-level interconnection and transfer conditions. Multi-level interconnection and transfer conditions refer to situations where there is no direct backup feeder path, requiring the connection of multiple non-faulty feeder segments through two or more interconnection switches to form an indirect backup power supply path. Suboptimal backup paths refer to backup paths with more transfer levels and slightly slower response times compared to the direct backup paths in the first stage, but which can still meet the load power supply requirements. Their selection requires that the current carrying capacity of all feeder segments on the path matches the remaining load, and that the controllability of the switching equipment on the path meets the requirements.

[0185] Furthermore, based on the selected suboptimal backup path, the distribution network monitoring device identifies all the corresponding automated switching equipment (including tie switches and sectionalizing switches at all levels) on the path, plans the operation type and operation sequence of each device, and generates a second-stage progressive load restoration control process.

[0186] The progressive load restoration control process refers to the process of gradually executing switching operations according to the path hierarchy, gradually expanding the power supply path, and gradually restoring power supply to the remaining unrestored distribution transformers. It is necessary to ensure that the distribution network load is evenly distributed and there is no risk of overload after each step of the operation.

[0187] In one embodiment, after the first-stage load transfer control process is executed, the power supply status is updated to show that distribution transformers No. 3, No. 4, and No. 1 have resumed power supply; the remaining distribution transformer in the power supply impact area that has not resumed power supply after the operation is distribution transformer No. 2 (located at the edge of the fault core area with no direct backup path).

[0188] The distribution network monitoring device traverses the entire distribution network topology and selects the second-best backup path: 10kV Chengnan Line → Tie Switch No. 3 → Chengxi Line No. 2 Section Switch → Chengxi Line → Tie Switch No. 1 → Chengdong Line No. 2-3 Feeder Section → No. 2 Distribution Transformer. This path is a two-level tie transfer (Chengnan Line is connected to Chengxi Line via Tie Switch No. 3, and Chengxi Line is connected to Chengdong Line via Tie Switch No. 1). Both Chengnan Line and Chengxi Line are non-faulty feeders with a total current carrying capacity of 400 Amps, which meets the load requirement of 80 Amps for No. 2 Distribution Transformer. Tie Switch No. 3 and Chengxi Line No. 2 Section Switch on the path are both non-operating abnormal devices.

[0189] The second-stage progressive load restoration control process is generated based on the suboptimal backup path: "Step 1: Close the No. 1 section switch of the Chengnan Line (activate the backup power supply of the Chengnan Line); Step 2: Close the No. 3 tie switch (connect the Chengnan Line and the Chengxi Line); Step 3: Close the No. 2 section switch of the Chengxi Line (extend the power supply path of the Chengxi Line); Step 4: Confirm that the No. 1 tie switch remains closed; Step 5: Close the No. 2 section switch of the Chengdong Line (connect to the No. 2 distribution transformer)."

[0190] Step 4044: Sequentially process the first-stage load transfer control process and the second-stage progressive load recovery control process according to the recovery priority and timing dependency to obtain the fault handling logic process.

[0191] Optionally, the restoration priority rule in this embodiment of the invention is as follows: the restoration priority of the emergency distribution transformer (the object to be restored first and the object to be restored after secondary power loss due to malfunction) corresponding to the first stage load transfer control process is higher than that of the remaining unrestored distribution transformers corresponding to the second stage progressive load restoration control process. Therefore, the overall priority of the first stage process is higher than that of the second stage process.

[0192] Optionally, the distribution network monitoring device analyzes the timing dependency between the two stages of the process. The timing dependency refers to the fact that the execution result of the previous stage is a prerequisite for the execution of the next stage. Specifically, the updated power supply state formed after the execution of the first stage provides the basic state (such as the activation state of the backup feeder and the closing state of the tie switch) for the selection and operation of the suboptimal backup path in the second stage. If the first stage is not executed, the path of the second stage cannot form a complete connection.

[0193] Furthermore, based on the recovery priority and timing dependency, the distribution network monitoring device sequentially integrates the first-stage load transfer control process and the second-stage progressive load restoration control process. During the integration process, it is necessary to ensure that the operation instructions of the two processes do not conflict and the operation timing does not overlap. For related operation objects (such as the same tie switch), the operation sequence and status maintenance requirements in different processes are clarified to obtain the fault handling logic process.

[0194] In one embodiment, the first-stage load transfer control process has a priority of Level 1, with the core objective of quickly restoring power supply to distribution transformers 1, 3, and 4. The second-stage progressive load restoration control process has a priority of Level 2, with the core objective of restoring power supply to distribution transformer 2, and depends on the closing status of tie switch 1 in the first-stage process. The distribution network monitoring device analyzes the timing dependencies: the "confirm tie switch 1 remains closed" step in the second-stage process requires the completion of "tied switch 1 closing" in the first-stage process as a prerequisite and cannot be executed in advance.

[0195] Furthermore, the fault handling logic flow is integrated according to priority and time sequence dependencies: "Phase 1 (Emergency Recovery): 1. Close the No. 1 section switch of the West City Line; 2. Close the No. 1 connecting switch; 3. Close the No. 1 section switch of the North City Line; 4. Close the No. 2 connecting switch; Phase 2 (Gradual Recovery): 1. Close the No. 1 section switch of the South City Line; 2. Close the No. 3 connecting switch; 3. Close the No. 2 section switch of the West City Line; 4. Confirm that the No. 1 connecting switch remains closed; 5. Close the No. 2 section switch of the East City Line."

[0196] The embodiments of the present invention take into account equipment controllability, path availability and load priority, so that the generated fault handling logic flow is both comprehensive and operable, thereby improving the traceability and logical consistency of the fault handling process.

[0197] Furthermore, the distribution network automation monitoring device provided by the present invention will be described below. The distribution network automation monitoring device described below can be referred to in correspondence with the distribution network automation monitoring method described above.

[0198] Optionally, refer to Figure 2 , Figure 2 This is a schematic diagram of the structure of the distribution network automation monitoring device provided by the present invention. The distribution network automation monitoring device includes:

[0199] The fault monitoring module 210 is used to determine each automated switchgear on the faulty line and its initial switching state before the fault occurred, based on the real-time operating mode of the faulty line corresponding to the fault event at the time of the fault occurrence.

[0200] The switch status monitoring module 220 is used to determine the final expected switch status of the target switch after executing the target power outage simulation operation, based on the operation instruction type and initial switch status of the target switch, taking the automated switch corresponding to any target power outage simulation operation in the power outage simulation operation sequence associated with the fault event as the target switch.

[0201] The action anomaly analysis module 230 is used to update the power supply path connectivity based on the final expected switch state, obtain the power supply impact range after the operation, and determine the action anomaly judgment result based on the final expected switch state of each automated switch device in the corresponding power outage simulation operation and its actual action information within the fault event time window.

[0202] The fault handling module 240 is used to generate a fault handling logic flow for fault events based on the power supply impact range after the operation and the abnormal action judgment result.

[0203] This invention enables fault handling to proceed from real-time operational data acquisition at the moment of fault occurrence to deduction of expected operational states, verification of actual actions, and logical analysis of the entire process. This eliminates reliance on static network models and offline operation tickets, instead combining the actual operational mode at the moment of fault occurrence with the actual action behavior of automated switches. This achieves consistency verification between the operation sequence and the on-site physical response, improving the traceability and logical self-consistency of the fault handling process.

[0204] Please see Figure 3 , Figure 3 An embodiment diagram of an electronic device provided in accordance with the present invention. For example... Figure 3 As shown, an embodiment of the present invention provides an electronic device 300, including a memory 310, a processor 320, and a computer program 311 stored in the memory 310 and executable on the processor 320. When the processor 320 executes the computer program 311, it implements the processes of steps 10 to 40.

[0205] Please see Figure 4 , Figure 4 An embodiment diagram of a computer-readable storage medium provided in accordance with an embodiment of the present invention is shown. Figure 4 As shown, this embodiment provides a computer-readable storage medium 400 on which a computer program 311 is stored. When the computer program 311 is executed by a processor, it implements the processes of steps 10 to 40.

[0206] On the other hand, the present invention also provides a computer program product, which includes a computer program that can be stored on a non-transitory computer-readable storage medium. When the computer program is executed by a processor, the computer can execute the power distribution network automation monitoring method provided by the above methods, which includes steps 10 to 40.

[0207] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, and not to limit them; although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features; and these modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for automated monitoring of a distribution network, characterized in that, include: Based on the real-time operation mode of the faulty line corresponding to the fault event at the time of the fault occurrence, determine each automated switchgear on the faulty line and its initial switching state before the fault occurred. Taking any target power outage simulation operation in the power outage simulation operation sequence associated with the fault event as the target switchgear, the final expected switchgear state after the target power outage simulation operation is determined based on the operation instruction type and initial switch state of the target switchgear. The power supply path connectivity is updated based on the final expected switch state to obtain the power supply impact range after the operation. Based on the final expected switch state of each automated switch device in the corresponding power outage simulation operation and its actual action information within the fault event time window, the action anomaly judgment result is determined. Based on the power supply impact range after the operation and the abnormal action determination result, a fault handling logic flow is generated for the fault event. The steps involved in generating the fault handling logic flow for fault events include: Based on the power distribution network topology corresponding to the power supply impact range after the operation and the automatic switchgear whose action abnormality judgment result is failure to operate, the boundary automatic switchgear that is actually in the open state but is currently in the closed state due to failure to operate is identified. Based on the boundary automated switching equipment, adjacent non-faulty feeder segments that are electrically connected to the power supply impact range after the operation are identified, and the distribution transformers connected to the adjacent non-faulty feeder segments are identified as priority power restoration targets that were mistakenly included in the power outage range due to failure to operate. Based on the abnormal action judgment result of the automated switching equipment that was malfunctioned and the power supply branch that was mistakenly disconnected due to malfunction in the power supply influence range after the operation, the isolated non-faulty power supply island is identified, and the distribution transformer associated with the isolated non-faulty power supply island is identified as the object of secondary power loss recovery due to malfunction. Based on the priority power restoration objects, the secondary power loss restoration objects caused by malfunctions, and the automated switching equipment whose action anomaly determination result is no action anomaly, the fault handling logic flow is generated.

2. The distribution network automation monitoring method according to claim 1, characterized in that, The fault handling logic flow is generated based on the priority power restoration objects, the secondary power loss restoration objects caused by malfunctions, and the automated switching equipment whose action anomaly determination result is no action anomaly. This includes: Taking the priority power restoration target and the secondary power loss restoration target caused by malfunction as the emergency distribution transformer, the backup feeder path in the global topology of the distribution network that is connected to the emergency distribution transformer by a tie switch and is in an available state is traversed. Based on the backup feeder path and the automated switching equipment outside the power supply impact range after the operation that is not affected by the abnormal operation, a remote control operation sequence for switching the emergency distribution transformer to backup feeder power supply is determined. Based on the remote control operation sequence and the automatic switching equipment with no abnormal operation results, uncontrollable equipment due to communication interruption or remote control function lockout is excluded, a remote control operation instruction set is obtained, and the first stage load transfer control process is determined based on the remote control operation instruction set. Based on the updated power supply status after the execution of the first-stage load transfer control process and the remaining distribution transformers that have not been restored to power supply in the power supply impact range after the operation, a suboptimal backup path with multi-level interconnection transfer conditions is selected, and a second-stage progressive load restoration control process is generated based on the suboptimal backup path and its corresponding automated switching equipment. The first-stage load transfer control process and the second-stage progressive load recovery control process are sequentially arranged according to the recovery priority and timing dependency to obtain the fault handling logic process.

3. The distribution network automation monitoring method according to claim 1, characterized in that, The determination of the final expected switching state of the target switchgear after performing the target power outage simulation operation, based on the operation command type and initial switching state of the target switchgear, includes: Based on the switching action direction indicated in the operation instruction type and the initial switching state, determine the type of physical action that the target switching device should perform after receiving the operation instruction; Based on the type of physical action, determine whether the target switching device has the mechanical feasibility conditions to perform the action, and obtain the mechanical feasibility judgment result; Based on the mechanical feasibility assessment results, the initial expected switching state of the target switchgear is determined, and based on the initial expected switching state and the electrical topology location information of the feeder segment to which the target switchgear belongs, the constraint boundary of the initial expected switching state on the operation logic of adjacent switchgear is determined. The final expected switching state of the target switching device is determined based on the constraint boundary.

4. The distribution network automation monitoring method according to claim 3, characterized in that, Determining the final expected switching state of the target switching device based on the constraint boundary includes: Based on the constraint boundary, branches of the simulation operation sequence that conflict with the initial expected switching state are eliminated to obtain an effective simulation operation path; Based on the effective simulated operation path, the initial expected switch state is matched and verified with the bus power supply state in the real-time operation mode to obtain the matching and verification result; the matching and verification result is used to determine whether the initial expected switch state causes reverse power supply abnormality. If the matching verification result determines that there is no reverse power supply abnormality in the initial expected switch state, then the initial expected switch state is determined as the final expected switch state of the target switch device.

5. The distribution network automation monitoring method according to claim 3, characterized in that, The direction of switch action includes opening and closing commands; the initial switch state includes closed and open states. Determining the initial expected switching state of the target switchgear based on the mechanical feasibility assessment result includes: If the mechanical feasibility assessment result is feasible, and the operation command type is a tripping command, and the initial switch state is closed, then the initial expected switch state is determined to be a change from closed to open. If the mechanical feasibility assessment result is feasible, the operation command type is a closing command, and the initial switch state is open, then the initial expected switch state is determined to change from open to closed. If the mechanical feasibility assessment result is infeasible, and the operation command type is a trip command, and the initial switch state is open, then the initial expected switch state is determined to be open. If the mechanical feasibility assessment result is infeasible, and the operation command type is a closing command, and the initial switch state is closed, then the initial expected switch state is determined to be closed.

6. The distribution network automation monitoring method according to any one of claims 1 to 5, characterized in that, The steps for determining the abnormal action judgment result include: Based on the final expected switching state of each automated switchgear and the remote signaling change information and remote control execution feedback information in the actual action information, a state consistency judgment is made to obtain the state consistency result between the actual final switching state and the final expected switching state; the remote signaling change information includes the time of occurrence of the remote signaling change, the switching state before the change, and the switching state after the change. Based on the state consistency results, combined with the remote signaling status of the automated switching equipment within the event time window, whether there is a remote signaling change event in the actual action information, and the remote signaling change direction of the remote signaling change event, the action anomaly judgment result is determined.

7. The distribution network automation monitoring method according to claim 6, characterized in that, The steps for determining the abnormal action judgment result include: If the state consistency result is inconsistent, and there is no remote signaling change event in the actual action information, and the remote signaling state of the automated switchgear within the event time window remains the same as the initial switch state and opposite to the final expected switch state, then it is determined whether a remote control command corresponding to the final expected switch state was issued to the automated switchgear within the fault event time window, and whether the communication link between the automated switchgear and the master station is normal within the response time interval from the time the remote control command was issued to the end of the preset maximum response time limit thereafter; if a remote control command was issued and the communication link is normal within the response time interval, then the action abnormality judgment result is determined to be refusal to operate; If the state consistency result is inconsistent, and there is a remote signal change event in the actual action information, and the remote signal change direction of the remote signal change event is opposite to the direction of the final expected switch state, then it is determined whether there is an interlock action signal within the fault event time window; if there is an interlock action signal, and the remote signal change direction is not related to any control command, then the action abnormality judgment result is determined to be a false operation. If the state consistency result is consistent, and there is a remote signal change event in the actual action information, and the remote signal change direction of the remote signal change event is consistent with the direction of the final expected switch state, then it is determined whether the occurrence time of the remote signal change is within the response time interval from the time the remote control command is issued to the end of the preset maximum response time limit thereafter; if the occurrence time of the remote signal change is within the response time interval, then it is determined that the action anomaly determination result is determined to be no action anomaly. If the state consistency result is consistent, and there is no remote signaling change event in the actual action information, and the remote signaling state of the automated switchgear within the event time window remains the same as the final expected switch state, then the action anomaly determination result is determined to be no action anomaly.

8. A power distribution network automation monitoring device, characterized in that, Used to implement the power distribution network automated monitoring method as described in any one of claims 1 to 7; The power distribution network automation monitoring device includes: The fault monitoring module is used to determine each automated switchgear on the faulty line and its initial switching state before the fault occurred, based on the real-time operating mode of the faulty line corresponding to the fault event at the time of the fault occurrence. The switch status monitoring module is used to determine the final expected switch status of the target switch after executing the target power outage simulation operation, based on the operation instruction type and initial switch status of the target switch, taking any target power outage simulation operation corresponding to the target switch in the power outage simulation operation sequence associated with the fault event. The action anomaly analysis module is used to update the power supply path connectivity based on the final expected switch state, obtain the power supply impact range after the operation, and determine the action anomaly judgment result based on the final expected switch state of each automated switch device in the corresponding power outage simulation operation and its actual action information within the fault event time window. The fault handling module is used to generate a fault handling logic flow for the fault event based on the power supply impact range after the operation and the abnormal action determination result. The steps involved in generating the fault handling logic flow for fault events include: Based on the power distribution network topology corresponding to the power supply impact range after the operation and the automatic switchgear whose action abnormality judgment result is failure to operate, the boundary automatic switchgear that is actually in the open state but is currently in the closed state due to failure to operate is identified. Based on the boundary automated switching equipment, adjacent non-faulty feeder segments that are electrically connected to the power supply impact range after the operation are identified, and the distribution transformers connected to the adjacent non-faulty feeder segments are identified as priority power restoration targets that were mistakenly included in the power outage range due to failure to operate. Based on the abnormal action judgment result of the automated switching equipment that was malfunctioned and the power supply branch that was mistakenly disconnected due to malfunction in the power supply influence range after the operation, the isolated non-faulty power supply island is identified, and the distribution transformer associated with the isolated non-faulty power supply island is identified as the object of secondary power loss recovery due to malfunction. Based on the priority power restoration objects, the secondary power loss restoration objects caused by malfunctions, and the automated switching equipment whose action anomaly determination result is no action anomaly, the fault handling logic flow is generated.

9. A non-transitory computer-readable storage medium, wherein a computer software program is stored therein, characterized in that, When the computer software program is executed by the processor, it implements the power distribution network automation monitoring method as described in any one of claims 1 to 7.

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