Transformer substation remote control information checking method, system and device and terminal equipment

Abstract

The invention is suitable for the technical field of transformer substations, and provides a transformer substation remote control information checking method, system and device and terminal device.The method comprises the steps that in a simulation test environment, a first remote control instruction from a monitoring background and a second remote control instruction from a dispatching master station are received, first remote control information is generated based on the first remote control instruction, and second remote control information is generated based on the second remote control instruction; checking the consistency of the first remote control information and the second remote control information; wherein the simulation test environment is constructed based on a substation system configuration description file and is used for simulating the spacer layer device and receiving a remote control instruction. The remote control command transmission link and the execution effect can be comprehensively verified, the accuracy and the reliability of the remote control command are ensured, and safe and stable operation of a transformer substation and a whole power system is guaranteed.

Description

Technical Field

[0001] This application relates to the field of substation technology, and in particular to a method, system, device and terminal equipment for verifying remote control information of a substation. Background Technology

[0002] With the deepening development of smart grid construction, the automation level of substations is increasing, and substations have gradually formed an automated system architecture consisting of a dispatch master station (hereinafter referred to as the master station), a communication network, and station-end equipment. The master station interacts with station-end equipment such as switchgear, relay protection devices, and measurement and control devices within the substation through the communication network, realizing remote monitoring and operation of the station-end equipment. This remote control mode based on digital communication has become a core technological support for ensuring the safe and stable operation of the smart grid. The remote control function, as an important function for interaction between the master station and station-end equipment, undertakes the crucial task of translating dispatch commands into actual equipment actions. Its accuracy and reliability directly affect the rational allocation of power grid resources and the efficiency of fault handling.

[0003] However, in practical applications, differences in communication protocol understanding, incorrect remote control point table configuration, and changes in equipment logic parameters can lead to errors, frame drops, or semantic parsing deviations in remote control data transmission between the master station and station-end equipment. This can result in safety risks such as miscontrol or refusal to control. The compatibility of remote control logic between old and new equipment becomes even more prominent after substation equipment updates, system upgrades, or network structure adjustments. Traditional manual verification or simple signal checking methods are insufficient to fully cover potential hazards in complex scenarios.

[0004] Therefore, how to achieve comprehensive verification of the remote control command transmission link and execution effect, ensure the accuracy and reliability of remote control commands, and guarantee the safe and stable operation of substations and the entire power system is a problem that needs to be solved. Summary of the Invention

[0005] This application provides a method, system, device, and terminal equipment for verifying remote control information in substations. It can comprehensively verify the transmission link and execution effect of remote control commands, ensure the accuracy and reliability of remote control commands, and guarantee the safe and stable operation of substations and the entire power system.

[0006] In a first aspect, embodiments of this application provide a method for verifying remote control information of a substation, including:

[0007] In a simulation test environment, a first remote control command is received from the monitoring backend, and first remote control information is generated based on the first remote control command;

[0008] In the simulation test environment, a second remote control command is received from the scheduling master station, and second remote control information is generated based on the second remote control command;

[0009] Perform a consistency check on the first remote control information and the second remote control information;

[0010] The simulation test environment is built based on the substation system configuration description file and is used to simulate bay layer devices and receive remote control commands.

[0011] In one possible implementation of the first aspect, the step of verifying the consistency of the first remote control information and the second remote control information includes:

[0012] Compare whether the fields in the first remote control information and the second remote control information are consistent;

[0013] If the fields are consistent, the field consistency check is considered passed.

[0014] In one possible implementation of the first aspect, the field includes an IP address, an MMS index, a remote control value, a remote control type, and a remote control signal description.

[0015] In one possible implementation of the first aspect, the method further includes:

[0016] Import the remote control configuration description file or the remote control point table of the dispatch master station;

[0017] Based on the remote control configuration description file, the first remote control information, and the second remote control information, a three-party logical consistency check is performed.

[0018] Alternatively, a three-party logical consistency check can be performed based on the remote control point table of the scheduling master station, the first remote control information, and the second remote control information.

[0019] In one possible implementation of the first aspect, the execution of the three-party logical consistency check includes:

[0020] Obtain the preset point table order, which is determined based on the remote control configuration description file or the remote control point table of the dispatch master station.

[0021] The three-party logical consistency check is performed point by point according to the preset point table.

[0022] In one possible implementation of the first aspect, before the step of receiving the first remote control command from the monitoring backend and the step of receiving the second remote control command from the dispatch master station, the method further includes:

[0023] Obtain the system configuration description file;

[0024] A simulation test environment is built based on the system configuration description file.

[0025] In one possible implementation of the first aspect, after the step of verifying the consistency of the first remote control information and the second remote control information, the method further includes:

[0026] If the consistency check fails, record the check error;

[0027] A verification error report is generated based on the verification error records, and the verification error report is sent to the designated user.

[0028] Secondly, embodiments of this application provide a substation remote control information verification system, including simulation equipment, a monitoring backend, and a dispatch master station, wherein:

[0029] The monitoring backend is used to send a first remote control command to the simulation device;

[0030] The scheduling master station is used to send a second remote control command to the simulation device;

[0031] The simulation device is used to receive a first remote control command from the monitoring backend and a second remote control command from the dispatch master station in a simulation test environment, and generate first remote control information based on the first remote control command and second remote control information based on the second remote control command; and to perform consistency verification on the first remote control information and the second remote control information.

[0032] The simulation test environment is built based on the substation system configuration description file and is used to simulate bay layer devices and receive remote control commands.

[0033] Thirdly, embodiments of this application provide a substation remote control information verification device, comprising:

[0034] The first information acquisition unit is used to receive a first remote control command from the monitoring backend in a simulation test environment, and generate first remote control information based on the first remote control command.

[0035] The second information acquisition unit is used to receive a second remote control command from the scheduling master station in the simulation test environment, and generate second remote control information based on the second remote control command.

[0036] The first verification unit is used to verify the consistency of the first remote control information and the second remote control information.

[0037] The simulation test environment is built based on the substation system configuration description file and is used to simulate bay layer devices and receive remote control commands.

[0038] Fourthly, embodiments of this application provide a terminal device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the substation remote control information verification method as described in the first aspect above.

[0039] Fifthly, embodiments of this application provide a computer-readable storage medium storing a computer program that, when executed by a processor, implements the substation remote control information verification method as described in the first aspect above.

[0040] Sixthly, embodiments of this application provide a computer program product that, when run on a terminal device, causes the terminal device to execute the substation remote control information verification method described in the first aspect above.

[0041] In this embodiment, by receiving and parsing dual-link remote control commands from the monitoring backend and the dispatch master station in a simulation test environment built based on the substation system configuration description file, standardized first and second remote control information are generated. The consistency of these two information is then verified, effectively validating the accuracy of the complete transmission link of remote control commands from the master station system to the bay-level devices. This application's solution realistically recreates the substation communication protocol environment through simulation, ensuring that the verification results reflect actual operating conditions. The dual-link command receiving mechanism synchronously captures direct commands from the monitoring backend and commands from the dispatch master station, covering the critical path of remote control command transmission. By comparing the two remote control information streams, protocol parsing errors, data loss, or mapping deviations during transmission are accurately identified, eliminating the risk of miscontrol or refusal to control due to unreliable communication links at the source. This achieves comprehensive verification of the remote control command transmission link and execution effect, ensuring the accuracy and reliability of remote control commands, and thus guaranteeing the safe and stable operation of the substation and the entire power system. Attached Figure Description

[0042] To more clearly illustrate the technical solutions in the embodiments of this application, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0043] Figure 1 This is a system architecture diagram of the substation remote control information verification system provided in the embodiments of this application;

[0044] Figure 1.1 This is a schematic diagram of the architecture of the substation remote control information verification system provided in the embodiments of this application;

[0045] Figure 2This is a flowchart illustrating the implementation of the substation remote control information verification method provided in this application embodiment;

[0046] Figure 3 This is a flowchart illustrating a specific implementation of step S203 in the substation remote control information verification method provided in this application embodiment;

[0047] Figure 4 This is a flowchart illustrating a specific implementation of the three-party consistency verification method in the substation remote control information verification method provided in this application embodiment;

[0048] Figure 5 This is another specific implementation flowchart of the three-party consistency verification in the substation remote control information verification method provided in this application embodiment;

[0049] Figure 6 This is a structural block diagram of the substation remote control information verification device provided in the embodiments of this application;

[0050] Figure 7 This is a schematic diagram of the terminal device provided in the embodiments of this application. Detailed Implementation

[0051] In the following description, specific details such as particular system architectures and techniques are set forth for illustrative purposes and not for limitation, in order to provide a thorough understanding of the embodiments of this application. However, those skilled in the art will understand that this application may also be implemented in other embodiments without these specific details. In other instances, detailed descriptions of well-known systems, apparatuses, circuits, and methods have been omitted so as not to obscure the description of this application with unnecessary detail.

[0052] It should be understood that, when used in this application specification and the appended claims, the term "comprising" indicates the presence of the described features, integrals, steps, operations, elements and / or components, but does not exclude the presence or addition of one or more other features, integrals, steps, operations, elements, components and / or a collection thereof.

[0053] It should also be understood that the term “and / or” as used in this application specification and the appended claims means any combination of one or more of the associated listed items and all possible combinations, and includes such combinations.

[0054] As used in this application specification and the appended claims, the term "if" may be interpreted, depending on the context, as "when," "once," "in response to determination," or "in response to detection." Similarly, the phrase "if determined" or "if detected [the described condition or event]" may be interpreted, depending on the context, as meaning "once determined," "in response to determination," "once detected [the described condition or event]," or "in response to detection [the described condition or event]."

[0055] Furthermore, in the description of this application and the appended claims, the terms "first," "second," "third," etc., are used only to distinguish descriptions and should not be construed as indicating or implying relative importance.

[0056] References to "one embodiment" or "some embodiments" as described in this specification mean that one or more embodiments of this application include a specific feature, structure, or characteristic described in connection with that embodiment. Therefore, the phrases "in one embodiment," "in some embodiments," "in other embodiments," "in still other embodiments," etc., appearing in different parts of this specification do not necessarily refer to the same embodiment, but rather mean "one or more, but not all, embodiments," unless otherwise specifically emphasized. The terms "comprising," "including," "having," and variations thereof mean "including but not limited to," unless otherwise specifically emphasized.

[0057] The substation remote control information verification method provided in this application is applicable to various types of terminal devices that need to perform substation remote control information verification. Specific terminal devices may include mobile phones, tablets, wearable devices, laptops, ultra-mobile personal computers (UMPCs), desktop computers, interactive large screens, and servers, etc. This application does not impose any restrictions on the specific type of terminal device.

[0058] Figure 1 The system architecture diagram of the substation remote control information verification system provided in the embodiment of this application is shown, and is described in detail below: For ease of explanation, only the parts related to the embodiment of this application are shown.

[0059] Reference Figure 1 The substation remote control information verification system includes simulation equipment 1, monitoring backend 2, and dispatch master station 3, wherein:

[0060] The monitoring backend 2 is used to send the first remote control command to the simulation device 1.

[0061] The scheduling master station 3 is used to send a second remote control command to the simulation device 1.

[0062] The simulation device 1 is used to receive a first remote control command from the monitoring backend 2 and a second remote control command from the dispatch master station 3 in a simulation test environment, and generate first remote control information based on the first remote control command and second remote control information based on the second remote control command; and to perform consistency verification on the first remote control information and the second remote control information.

[0063] The simulation test environment is built based on the substation system configuration description file and is used to simulate bay layer devices and receive remote control commands.

[0064] In this embodiment, simulation device 1 is a terminal device equipped with a simulation system, which is used to simulate the substation remote control information verification environment.

[0065] Monitoring backend 2 is typically located at the substation control layer, focusing on local monitoring and operation of equipment within the substation. For example, it can monitor the real-time status of switchgear (such as open / closed status), current, voltage, and other electrical parameters. Staff can intuitively view the substation equipment's operating status on the human-machine interface of monitoring backend 2 and perform routine local control operations, such as verifying the opening and closing operations of switchgear.

[0066] The master dispatch station 3 is typically located in a remote location such as a power dispatch center. Its primary function is to dispatch and manage the operation of multiple substations from a macro-level perspective. The master dispatch station 3 interacts with each substation via a communication network, collecting operational data such as equipment status information and power quality data. Based on this data, the master dispatch station 3 can formulate power grid operation strategies, such as adjusting generation plans and allocating loads. When remote operation of substation equipment is required, the master dispatch station 3 issues remote control commands to achieve centralized control and optimization of the power grid's operational status.

[0067] Simulation device 1 can be a terminal device with communication capabilities, such as a mobile phone, tablet, wearable device, laptop, ultra-mobile personal computer (UMPC), desktop computer, interactive large screen, or server. Simulation device 1 can be connected to the monitoring backend 2 via a wired connection. Figure 1.1 As shown, simulation device 1 is connected to dispatch master station 3 via a data gateway. The data gateway is mainly used to realize data exchange between internal equipment in the substation and external systems (such as dispatch center, control center, etc.). In this embodiment, the data gateway plays a crucial bridging role in the communication process between dispatch master station 3 and simulation device 1. It can convert between different communication protocols, ensuring that data between dispatch master station 3 and simulation device 1 can be transmitted accurately and reliably. For example, when the communication protocol used by dispatch master station 3 is inconsistent with the communication protocol of simulation device 1, the data gateway can convert the data protocol, enabling the two parties to communicate normally.

[0068] In this embodiment, a wired connection between the data gateway and the simulation device 1 can be established using a general network port or serial port technology. This embodiment does not impose any restrictions on the communication connection method between the devices.

[0069] Figure 2 The implementation flow of the substation remote control information verification method provided in this application embodiment is shown. The method flow includes steps S201 to S203. In this embodiment, the execution entity of the flow is... Figure 1 The specific implementation principles of each step in the simulation device 1 shown are as follows:

[0070] Step S201: In a simulation test environment, receive the first remote control command from the monitoring backend, and generate the first remote control information based on the first remote control command.

[0071] In this embodiment, a simulation test environment is pre-built based on the substation system configuration description file to simulate bay-level devices and receive remote control commands. The bay-level devices are responsible for collecting real-time operating data of the power system, such as current, voltage, and power parameters, from the process layer (including various sensors, circuit breakers, disconnectors, etc.), and performing preliminary processing and calculations. Based on the collected data and preset protection logic, the bay-level devices can achieve protection control of substation equipment, such as overcurrent protection and differential protection, to ensure the safe and stable operation of the power system. The bay-level devices also undertake communication tasks with the station control layer and other bay-level devices. Through standard communication protocols (such as IEC61850), they upload processed information to the station control layer (such as the monitoring backend and data gateway) and receive control commands from the station control layer.

[0072] One possible implementation involves obtaining a System Configuration Description (SCD) file and building a simulation test environment based on the SCD file.

[0073] The simulation system on the simulation equipment is used to parse information such as communication parameters, device models, and signal connection relationships in the SCD file, and then construct a simulation test environment based on the parsing results. This simulation test environment simulates the communication interface and logical functions of the interval layer device, and can interact with the station control layer such as the monitoring backend and the dispatch master station (through the data gateway), providing a basic platform for subsequent remote control command reception and verification.

[0074] Building a simulation test environment based on SCD files effectively solves the problem of traditional verification lacking realistic simulation scenarios, ensuring that the subsequent verification process is highly consistent with the actual operating environment, thereby improving the credibility of the verification results.

[0075] In one possible implementation, the monitoring backend, based on the security status verified by local remote control, issues the first remote control command to the simulation device according to the point list order in the Remote Configuration Description (RCD) file. In another possible implementation, the monitoring backend, based on the security status verified by local remote control, issues the first remote control command to the simulation device according to the master station remote control point list order.

[0076] In a simulated testing environment, the simulation device receives the first remote control command sent by the monitoring backend, parses the command, and generates first remote control information based on the parsing results. This first remote control information accurately describes the details of the first remote control command issued by the monitoring backend. It includes, but is not limited to, fields such as IP address (identifying the device's location on the network), MMS index (Manufacturing Message Specification Index, used to uniquely identify a specific remote control point or device in the communication protocol), remote control value (indicating the specific remote control operation, such as the on / off state of a switch), remote control type (such as preset, execute, or cancel operation), and remote control signal description (a detailed description of the remote control signal, possibly including device name, function, etc.). The first remote control information generated by the simulation device provides the data foundation for subsequent consistency verification.

[0077] Step S202: In the simulation test environment, a second remote control command is received from the scheduling master station, and second remote control information is generated based on the second remote control command.

[0078] The master dispatch station sends a second remote control command to the simulation device through the data gateway according to its own control logic. The simulation device receives the second remote control command sent by the master dispatch station in the simulation test environment and generates second remote control information based on the second remote control command.

[0079] In one possible implementation, the master dispatch station issues the second remote control command to the simulation device according to the point list order in the RCD file. In another possible implementation, the master dispatch station issues the second remote control command to the simulation device according to the master station remote control point list order.

[0080] To ensure the accuracy and effectiveness of consistency verification, the point table order used by the monitoring backend to send the first remote control command to the simulation device and the dispatch master station to send the second remote control command to the simulation device comes from the same source. That is, both the monitoring backend and the dispatch master station follow the point table order in the RCD file, or both follow the remote control point table order of the master station.

[0081] In a simulated testing environment, the simulation equipment receives a second remote control command sent by the scheduling master station, parses the command, and generates second remote control information based on the parsing results. This second remote control information accurately describes the details of the second remote control command issued by the scheduling master station. It includes, but is not limited to, fields such as IP address, MMS index, remote control value, remote control type, and remote control signal description. The second remote control information generated by the simulation equipment provides the data foundation for subsequent consistency verification.

[0082] Step S203: Perform a consistency check on the first remote control information and the second remote control information.

[0083] After generating the first and second remote control information, the simulation equipment initiates a process to verify the consistency between the two information. This consistency check verifies the accuracy and reliability of the remote control operation.

[0084] As one possible implementation of this application Figure 3 A specific implementation flow of step S203 of the substation remote control information verification method provided in this application embodiment is shown below:

[0085] A1: Compare whether the fields in the first remote control information and the second remote control information are consistent.

[0086] In one possible implementation, the fields include IP address, MMS index, remote control value, remote control type, and remote control signal description. Verification is made to confirm whether the remote control commands (first and second remote control commands) are sent to the same target device by verifying whether the IP addresses in the first and second remote control information are consistent; verification is made to determine whether the remote control points pointed to by the remote control commands are consistent by verifying whether the remote control values ​​in the first and second remote control information are consistent by verifying whether the operation content (e.g., the on / off state of a switch) is consistent by verifying whether the remote control types in the first and second remote control information are consistent by verifying whether the operation nature (preset, execute, or cancel) is consistent by verifying whether the remote control signal descriptions in the first and second remote control information are consistent by verifying whether the detailed information of the remote control command is correct.

[0087] A2: If the fields are consistent, the consistency check is considered passed.

[0088] A3: If the fields are inconsistent, the consistency check is deemed to have failed.

[0089] If all fields in the first and second remote control information match perfectly, the system will determine that the consistency check has passed. This indicates that the remote control commands sent by the monitoring backend and the dispatch master station are consistent in content, and no errors or deviations occurred during transmission, thus ensuring the accuracy and reliability of the remote control operation. Conversely, if any field in the first and second remote control information is inconsistent, the system will determine that the consistency check has failed.

[0090] In this embodiment of the application, by comparing whether the fields in the first remote control information and the second remote control information are consistent, it is possible to promptly detect problems such as parameter errors and protocol parsing deviations that may occur during the instruction transmission process between the main station and the monitoring backend, thereby avoiding the risk of miscontrol or refusal to control due to inconsistent instructions and effectively ensuring the accuracy of remote control command execution.

[0091] In one possible implementation, the fields in the remote control information may also include a timestamp (used to record the time when the remote control command is generated or sent), a checksum (used to verify whether data errors have occurred during the transmission of the remote control information; common checksums include Cyclic Redundancy Check (CRC), checksums, etc.), a device status identifier (used to indicate the current status of the target device, such as the "closed" or "open" status of a circuit breaker, the "open" or "closed" status of a disconnector switch, etc.), and a priority identifier (used to distinguish the importance and execution order of multiple remote control commands).

[0092] By comparing the timestamps in the first and second remote control information, the system verifies whether the order of remote control commands from the monitoring backend and the dispatch master station matches expectations. This prevents equipment malfunctions caused by command transmission delays or out-of-order execution. Inconsistent timestamps may lead to command delays or out-of-order execution. Verifying the consistency of checksums in the first and second remote control information verifies whether data errors occurred during remote control command transmission, ensuring that received remote control commands have not been tampered with or have been corrupted by interference. Verifying the consistency of device status identifiers in the first and second remote control information determines whether the current device status is normal, preventing safety accidents caused by remote control operations performed under abnormal device conditions. In substation operation, multiple remote control commands often occur concurrently, with varying degrees of importance and urgency. By comparing the priority identifiers of commands in the first and second remote control information, the system ensures that the dispatch master station and monitoring backend have consistent understanding of command priorities, thereby guaranteeing that remote control operations are performed according to the correct priority order and improving the efficiency and accuracy of power grid emergency response.

[0093] As one possible implementation of this application Figure 4 This application provides a specific implementation process for tripartite consistency verification in the substation remote control information verification method, as detailed below:

[0094] B1: Import the remote control configuration description file (RCD file). The RCD file is a configuration file that records in detail the configuration information of the substation remote control system, including the remote control point number sequence, parameter settings of the remote control objects, communication parameters with the dispatch master station and monitoring backend, and other third-party remote control information.

[0095] B2: Based on the remote control configuration description file, the first remote control information, and the second remote control information, perform a three-party logical consistency check. The "three parties" refer to the third remote control information contained in the RCD file, the first remote control information generated according to the first remote control instruction, and the second remote control information generated according to the second remote control instruction.

[0096] In this embodiment, an RCD file is imported into the simulation device, and the RCD file is parsed in the simulation test environment to obtain the third remote control information in the RCD file. Based on this third remote control information, the first remote control information, and the second remote control information, a three-way logical consistency check is performed. The third remote control information in the RCD file provides an accurate reference benchmark for the entire check process, ensuring that the check of remote control commands issued by the monitoring backend and the dispatch master station has a unified and reliable standard, avoiding check deviations caused by a lack of standardized references, thereby ensuring the accuracy and authority of the check results.

[0097] As one possible implementation of this application Figure 5 The following is a detailed description of another specific implementation process for consistency verification in the substation remote control information verification method provided in this application:

[0098] C1: Import the remote control point table of the dispatch master station. The remote control point table of the dispatch master station is a configuration file containing detailed information on all remote control points, including the unique identifier of each remote control point (such as point number), the corresponding equipment information (such as circuit breaker, disconnector), the expected operating parameters (such as opening and closing status), and the operation sequence, etc., which is the fourth type of remote control information.

[0099] C2: Based on the remote control point table of the scheduling master station, the first remote control information, and the second remote control information, perform a three-party logical consistency check. The "three parties" refer to the fourth remote control information contained in the remote control point table of the scheduling master station, the first remote control information generated according to the first remote control instruction, and the second remote control information generated according to the second remote control instruction.

[0100] In this embodiment, the simulation device imports a remote control point table from the dispatch master station. Under the simulation test environment, the remote control point table is parsed to obtain the fourth remote control information. Based on this fourth remote control information, the first remote control information, and the second remote control information, a three-way logical consistency check is performed. This embodiment ensures that the simulation device can obtain the original intent of the dispatch master station for remote control operations under the simulation test environment. This provides an authoritative reference for subsequent comparison of remote control commands issued by the monitoring backend and the dispatch master station, avoiding verification deviations caused by inconsistent reference standards, thereby ensuring the accuracy and reliability of the verification results.

[0101] As one possible implementation of this application, performing a three-party logical consistency check includes:

[0102] D1: Obtain the preset point table order, which is determined based on the telecontrol configuration description file or the remote control point table of the dispatch master station.

[0103] The preset point table order refers to the order of remote control points predefined in the remote control configuration description file or the remote control point table of the dispatch master station. This order is usually determined based on the operating logic of the substation equipment and dispatching requirements, ensuring the orderly and standardized operation of remote control. Obtaining the preset point table order provides a clear operating sequence and reference benchmark for subsequent three-party logical consistency verification. By performing verification according to the preset point table order, the systematic and comprehensive nature of the verification process can be ensured, avoiding omissions or duplicate verification of certain remote control points, thereby improving the efficiency and accuracy of the verification.

[0104] D2: Perform the three-party logical consistency check point by point according to the preset point table.

[0105] Point-by-point execution of three-party logical consistency verification refers to the process of sequentially verifying the logical consistency of each remote control point according to a preset point table. Specifically, it involves using the remote control information in the remote control configuration description file (or the remote control information in the dispatch master station's remote control point table) as a baseline, comparing it point-by-point with the first remote control information generated by the monitoring backend and the second remote control information generated by the dispatch master station. After the verification of the current point is completed, the system automatically switches to the next remote control point. The comparison includes key fields such as the remote control point's IP address, MMS index, remote control value, remote control type, and remote control signal description, ensuring that these three information sources are logically consistent.

[0106] In this embodiment, performing point-to-point three-party logical consistency checks ensures that the operational intent and execution results of each remote control point meet expectations, effectively avoiding misoperations or equipment failures caused by inconsistent remote control information. By checking point by point according to a preset point list, the accuracy and reliability of the substation remote control system can be systematically checked and verified, potential problems can be identified and corrected in a timely manner, and the safe and stable operation of the substation and the entire power system can be guaranteed.

[0107] The simulation device supports the point-to-point issuance of first and second remote control commands from the monitoring backend and the dispatch master station. In one possible implementation, the simulation device also supports the following: after the first remote control command is issued to the simulation device point by point according to a preset point table, the second remote control command is issued to the dispatch master station according to the preset point table. After receiving the first and second remote control commands, the simulation device compares each command in turn.

[0108] As one possible implementation of this application, when the consistency check fails, a check error is recorded; a check error report is generated based on the check error record, and the check error report is sent to a designated user.

[0109] If a failure occurs during consistency verification or third-party logical consistency verification, the verification error is recorded, and a verification error report is generated according to the preset error handling mechanism. The verification error report specifically includes the time of the error, the remote control points involved, and the error type (such as field mismatch, disordered sequence, etc.). Then, the verification error report is sent to the designated user, such as the on-duty maintenance personnel, so that the maintenance personnel can promptly identify and handle the problem, ensuring the stable operation of the substation system.

[0110] In this embodiment, a complete remote control information verification system is formed, encompassing simulation environment construction, command reception and information generation, pairwise information verification, three-party logic verification, and error handling and feedback. Each step is closely interconnected; the preceding step provides the data and conditions for the following step, while the following step verifies and supplements the results of the preceding step. Ultimately, this achieves comprehensive verification of the remote control command transmission link and execution effect, effectively ensuring the accuracy and reliability of the remote control commands and providing a solid guarantee for the safe and stable operation of the substation and the entire power system.

[0111] As can be seen from the above, in this embodiment, by receiving and parsing dual-link remote control commands from the monitoring backend and the dispatch master station in a simulation test environment built based on the substation system configuration description file, standardized first and second remote control information are generated. The consistency of these two is then verified, effectively validating the accuracy of the complete transmission link of the remote control command from the master station system to the bay-level device. This application's solution realistically recreates the substation communication protocol environment through simulation, ensuring that the verification results reflect actual operating conditions. The dual-link command receiving mechanism synchronously captures direct commands from the monitoring backend and commands from the dispatch master station, covering the critical path of remote control command transmission. By comparing the two remote control information streams, protocol parsing errors, data loss, or mapping deviations during transmission are accurately identified, eliminating the risk of miscontrol or refusal to control due to unreliable communication links at the source. This achieves comprehensive verification of the remote control command transmission link and execution effect, ensuring the accuracy and reliability of the remote control commands, thereby guaranteeing the safe and stable operation of the substation and the entire power system.

[0112] It should be understood that the sequence number of each step in the above embodiments does not imply the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this application.

[0113] Corresponding to the substation remote control information verification method described in the above embodiments, Figure 6 The diagram shows a structural block diagram of a substation remote control information verification device provided in an embodiment of this application. For ease of explanation, only the parts related to the embodiment of this application are shown.

[0114] Reference Figure 6 The substation remote control information verification device includes: a first information acquisition unit 61, a second information acquisition unit 62, and a first verification unit 63, wherein:

[0115] The first information acquisition unit 61 is used to receive a first remote control command from the monitoring backend in a simulation test environment, and generate first remote control information based on the first remote control command.

[0116] The second information acquisition unit 62 is used to receive a second remote control command from the scheduling master station in the simulation test environment, and generate second remote control information based on the second remote control command.

[0117] The first verification unit 63 is used to verify the consistency of the first remote control information and the second remote control information.

[0118] The simulation test environment is built based on the substation system configuration description file and is used to simulate bay layer devices and receive remote control commands.

[0119] As one possible implementation of this application, the first verification unit 63 includes:

[0120] The first verification module is used to compare whether the fields in the first remote control information and the second remote control information are consistent; if the fields are consistent, the consistency verification is determined to be passed; if the fields are inconsistent, the consistency verification is determined to be failed.

[0121] As one possible implementation of this application, the fields include IP address, MMS index, remote control value, remote control type, and remote control signal description.

[0122] As one possible implementation of this application, the above-mentioned substation remote control information verification device further includes:

[0123] The first import unit is used to import the telemetry configuration description file;

[0124] The second import unit is used to import the remote control point table of the dispatch master station.

[0125] The second verification unit is used to perform a three-party logical consistency verification based on the remote control configuration description file, the first remote control information, and the second remote control information; or, based on the remote control point table of the scheduling master station, the first remote control information, and the second remote control information, to perform a three-party logical consistency verification.

[0126] As one possible implementation of this application, the second verification unit includes:

[0127] The point table order acquisition module is used to acquire a preset point table order, which is determined based on the remote control configuration description file or based on the remote control point table of the dispatch master station.

[0128] The three-party consistency verification module is used to perform three-party logical consistency verification point by point according to the preset point table.

[0129] As one possible implementation of this application, the above-mentioned substation remote control information verification device further includes:

[0130] The report sending unit is used to record the verification error when the consistency verification fails; generate a verification error report based on the verification error record; and send the verification error report to a designated user.

[0131] As can be seen from the above, in this embodiment, by receiving and parsing dual-link remote control commands from the monitoring backend and the dispatch master station in a simulation test environment built based on the substation system configuration description file, standardized first and second remote control information are generated. The consistency of these two is then verified, effectively validating the accuracy of the complete transmission link of the remote control command from the master station system to the bay-level device. This application's solution realistically recreates the substation communication protocol environment through simulation, ensuring that the verification results reflect actual operating conditions. The dual-link command receiving mechanism synchronously captures direct commands from the monitoring backend and commands from the dispatch master station, covering the critical path of remote control command transmission. By comparing the two remote control information streams, protocol parsing errors, data loss, or mapping deviations during transmission are accurately identified, eliminating the risk of miscontrol or refusal to control due to unreliable communication links at the source. This achieves comprehensive verification of the remote control command transmission link and execution effect, ensuring the accuracy and reliability of the remote control commands, thereby guaranteeing the safe and stable operation of the substation and the entire power system.

[0132] It should be noted that the information interaction and execution process between the above-mentioned devices / units are based on the same concept as the method embodiments of this application. For details on their specific functions and technical effects, please refer to the method embodiments section, and they will not be repeated here.

[0133] This application embodiment also provides a computer-readable storage medium storing a computer program, which, when executed by a processor, implements... Figures 2 to 5 The steps of any substation remote control information verification method are represented.

[0134] This application embodiment also provides a terminal device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements... Figures 2 to 5 The steps of any substation remote control information verification method are represented.

[0135] This application also provides a computer program product that, when run on a terminal device, causes the terminal device to execute the implementation of... Figures 2 to 5 The steps of any substation remote control information verification method are represented.

[0136] Figure 7 This is a schematic diagram of a terminal device provided in an embodiment of this application. For example... Figure 7 As shown, the terminal device 7 in this embodiment includes: a processor 70, a memory 71, and a computer program 72 stored in the memory 71 and executable on the processor 70. When the processor 70 executes the computer program 72, it implements the steps in the above embodiments of the substation remote control information verification methods, for example... Figure 2Steps S201 to S203 are shown. Alternatively, when the processor 70 executes the computer program 72, it implements the functions of each module / unit in the above-described device embodiments, for example... Figure 6 The functions of units 61 to 63 are shown.

[0137] For example, the computer program 72 may be divided into one or more modules / units, which are stored in the memory 71 and executed by the processor 70 to complete this application. The one or more modules / units may be a series of computer-readable instruction segments capable of performing a specific function, which describe the execution process of the computer program 72 in the terminal device 7.

[0138] The terminal device 7 may include, but is not limited to, a processor 70 and a memory 71. Those skilled in the art will understand that... Figure 7 This is merely an example of terminal device 7 and does not constitute a limitation on terminal device 7. It may include more or fewer components than shown, or combine certain components, or different components. For example, terminal device 7 may also include input / output devices, network access devices, buses, etc.

[0139] The processor 70 can be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. The general-purpose processor can be a microprocessor or any conventional processor.

[0140] The memory 71 can be an internal storage unit of the terminal device 7, such as a hard disk or memory of the terminal device 7. The memory 71 can also be an external storage device of the terminal device 7, such as a plug-in hard disk, smart media card (SMC), secure digital card (SD), flash card, etc., equipped on the terminal device 7. Furthermore, the memory 71 can include both internal and external storage units of the terminal device 7. The memory 71 is used to store the computer program and other programs and data required by the terminal device. The memory 71 can also be used to temporarily store data that has been output or will be output.

[0141] It should be noted that the information interaction and execution process between the above-mentioned devices / units are based on the same concept as the method embodiments of this application. For details on their specific functions and technical effects, please refer to the method embodiments section, and they will not be repeated here.

[0142] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the above-described division of functional units and modules is merely an example. In practical applications, the above functions can be assigned to different functional units and modules as needed, that is, the internal structure of the device can be divided into different functional units or modules to complete all or part of the functions described above. The functional units and modules in the embodiments can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit. Furthermore, the specific names of the functional units and modules are only for easy differentiation and are not intended to limit the scope of protection of this application. The specific working process of the units and modules in the above system can be referred to the corresponding process in the foregoing method embodiments, and will not be repeated here.

[0143] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, all or part of the processes in the methods of the above embodiments of this application can be implemented by a computer program instructing related hardware. The computer program can be stored in a computer-readable storage medium, and when executed by a processor, it can implement the steps of the various method embodiments described above. The computer program includes computer program code, which can be in the form of source code, object code, executable files, or certain intermediate forms. The computer-readable medium can include at least: any entity or device capable of carrying computer program code to a device / terminal equipment, a recording medium, a computer memory, a read-only memory (ROM), a random access memory (RAM), an electrical carrier signal, a telecommunication signal, and a software distribution medium. Examples include USB flash drives, portable hard drives, magnetic disks, or optical disks. In some jurisdictions, according to legislation and patent practice, computer-readable media cannot be electrical carrier signals or telecommunication signals.

[0144] In the above embodiments, the descriptions of each embodiment have different focuses. For parts that are not described in detail or recorded in a certain embodiment, please refer to the relevant descriptions of other embodiments.

[0145] The above-described embodiments are only used to illustrate the technical solutions of this application, and are not intended to limit them. Although this application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features. Such 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 this application, and should all be included within the protection scope of this application.

Claims

1. A method for verifying remote control information of a substation, characterized in that, include: In a simulation test environment, a first remote control command is received from the monitoring backend, and first remote control information is generated based on the first remote control command; In the simulation test environment, a second remote control command is received from the scheduling master station, and second remote control information is generated based on the second remote control command; Perform a consistency check on the first remote control information and the second remote control information; The simulation test environment is built based on the substation system configuration description file and is used to simulate bay layer devices and receive remote control commands.

2. The method according to claim 1, characterized in that, The step of verifying the consistency of the first remote control information and the second remote control information includes: Compare whether the fields in the first remote control information and the second remote control information are consistent; If the fields are consistent, the consistency check is considered passed. If the fields are inconsistent, the consistency check is deemed to have failed.

3. The method according to claim 2, characterized in that, The fields include IP address, MMS index, remote control value, remote control type, and remote control signal description.

4. The method according to claim 1, characterized in that, The method further includes: Import the remote control configuration description file or the remote control point table of the dispatch master station; Based on the remote control configuration description file, the first remote control information, and the second remote control information, a three-party logical consistency check is performed. Alternatively, a three-party logical consistency check can be performed based on the remote control point table of the scheduling master station, the first remote control information, and the second remote control information.

5. The method according to claim 4, characterized in that, The execution of the three-party logical consistency check includes: Obtain the preset point table order, which is determined based on the remote control configuration description file or the remote control point table of the dispatch master station. The three-party logical consistency check is performed point by point according to the preset point table.

6. The method according to any one of claims 1 to 5, characterized in that, After the step of verifying the consistency of the first remote control information and the second remote control information, the method further includes: If the consistency check fails, record the check error; A verification error report is generated based on the verification error records, and the verification error report is sent to the designated user.

7. A substation remote control information verification system, characterized in that, This includes simulation equipment, a monitoring backend, and a dispatch master station, among which: The monitoring backend is used to send a first remote control command to the simulation device; The scheduling master station is used to send a second remote control command to the simulation device; The simulation device is used to receive a first remote control command from the monitoring backend and a second remote control command from the dispatch master station in a simulation test environment, and generate first remote control information based on the first remote control command and second remote control information based on the second remote control command; and to perform consistency verification on the first remote control information and the second remote control information. The simulation test environment is built based on the substation system configuration description file and is used to simulate bay layer devices and receive remote control commands.

8. A substation remote control information verification device, characterized in that, include: The first information acquisition unit is used to receive a first remote control command from the monitoring backend in a simulation test environment, and generate first remote control information based on the first remote control command. The second information acquisition unit is used to receive a second remote control command from the scheduling master station in the simulation test environment, and generate second remote control information based on the second remote control command. The first verification unit is used to verify the consistency of the first remote control information and the second remote control information. The simulation test environment is built based on the substation system configuration description file and is used to simulate bay layer devices and receive remote control commands.

9. A terminal device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the substation remote control information verification method as described in any one of claims 1 to 6.

10. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by the processor, it implements the substation remote control information verification method as described in any one of claims 1 to 6.

Images