A smart substation secondary equipment pre-commissioning method and system

Abstract

The application discloses a kind of secondary equipment pre-commissioning method and system of intelligent substation, belong to the technical field of secondary equipment simulation system of intelligent substation, the method includes: first, configure primary system fault parameter and virtual protection setting rule, issue parameter to real-time digital simulation machine cabinet drive primary model simulation and output fault analog quantity;Virtual protection analysis obtains sampling, switch quantity data, according to protection setting control mechanism, judge obstacle, issue trip signal when fault, cabinet control model circuit breaker opens and cuts fault and returns system state;Finally, virtual protection analysis state data generates protection action report, completes one-two closed-loop simulation debugging.Through the application, the problem of poor debugging integrity and low efficiency of the prior art can be solved.

Description

Technical Field

[0001] This invention relates to the technical field of simulation systems for secondary equipment in intelligent substations, and particularly to a pre-commissioning method and system for secondary equipment in intelligent substations. Background Technology

[0002] Secondary protection equipment in intelligent substations is a core component for ensuring the safe and stable operation of the power grid. The equipment's operational logic, communication status, and fault response performance directly determine the substation's operation, maintenance, and fault handling capabilities. Therefore, the commissioning work before the equipment is put into operation is of utmost importance.

[0003] The current commissioning of secondary equipment in smart substations requires building test scenarios based on the physical primary equipment on-site, and relies on equipment wiring and commissioning coordination to conduct tests. This commissioning mode can only simulate a small number of fixed fault scenarios and cannot achieve complete primary and secondary coordinated commissioning, resulting in poor completeness of fault condition reproduction. The commissioning process lacks standardized and refined digital recording methods, and the records of fault data, communication status, and protection action information are messy, making it difficult for staff to identify hidden logical problems through manual judgment. At the same time, physical commissioning is constrained by the on-site environment, equipment status, and operating mode, resulting in limited commissioning coverage and accuracy, a long cycle, low overall commissioning efficiency, and operational safety hazards, as well as high costs in equipment, manpower, and time. Summary of the Invention

[0004] This invention provides a method and system for pre-commissioning secondary equipment in intelligent substations, which can solve the problems of poor commissioning integrity and low efficiency in existing technologies.

[0005] An embodiment of the present invention provides a method for pre-commissioning secondary equipment in a smart substation, comprising: Responding to the user's simulation setting operation, the system sets the corresponding fault test parameters for the primary system simulation model of the intelligent substation, and sets the protection setting control mechanism for the virtual protection device; The fault test parameters are sent to the real-time digital simulation device cabinet, so that the real-time digital simulation device cabinet drives the intelligent substation primary system simulation model to perform fault simulation according to the fault test parameters, generates fault simulation data, and generates measurement and control data messages based on the fault simulation data. Receive the measurement and control data messages generated by the real-time digital simulation device cabinet, and parse the measurement and control data messages through the virtual protection device to obtain real-time sampling data and switch quantity information; Based on the protection setting and control mechanism, fault determination is performed on real-time sampled data and switch quantity information; In the event of a fault, a trip signal is generated according to the protection setting and control mechanism and transmitted to the real-time digital simulation device cabinet. The real-time digital simulation device cabinet then drives the circuit breaker in the primary system simulation model of the intelligent substation to perform a tripping action based on the trip signal, thereby clearing the fault in the primary system simulation model of the intelligent substation. After the fault is cleared, the current operating status data of the primary system simulation model of the intelligent substation is generated and transmitted back to the virtual protection device. The virtual protection device analyzes the operating status data and generates protection action reports.

[0006] Furthermore, the real-time digital simulation device cabinet includes a network interface board; the network interface board is equipped with a sampling value communication module and a switch quantity communication module; the fault analog quantity data includes current analog quantity data and switch status information; The real-time digital simulation device cabinet generates measurement and control data messages based on fault simulation data, including: The analog current data is converted into sampled value messages through the sampled value communication module; The switch status information is converted into switch messages through the switch communication module. Sampled value messages and switch quantity messages are used as measurement and control data messages.

[0007] Furthermore, the system receives measurement and control data messages generated by the real-time digital simulation device cabinet, and parses these messages using a virtual protection device to obtain real-time sampling data and switch quantity information, including: The system receives measurement and control data messages generated by the real-time digital simulation device cabinet, and uses a virtual protection device to parse the sampled value messages and switch quantity messages in the measurement and control data messages to obtain real-time sampled data and switch quantity information.

[0008] Furthermore, based on the aforementioned protection setting and control mechanism, fault determination is performed on real-time sampled data and switch quantity information, including: Based on the switch input information, determine whether the protection function is allowed to be activated under the current operating condition; if it is determined that the protection function is not allowed to be activated, the fault determination is terminated directly. If it is determined that the protection function is allowed to be activated, then a half-wave Fourier transform operation is performed on the real-time sampled data to obtain the first phasor of the fundamental current. The change in the two-phase current difference of each group is calculated based on the first phasor, and the change in the two-phase current difference of each group is compared. The maximum value of the change in the two-phase current difference is taken as the global maximum phase current difference abrupt change. Fault determination is performed based on the protection setting and control mechanism, the global maximum phase current difference change, and the switching quantity information.

[0009] Furthermore, in the event of a fault, a trip signal is generated according to the aforementioned protection setting and control mechanism, including: If a fault is determined, the fault period is identified, and based on the fault period, the corresponding real-time fault sampling data is determined from the real-time sampling data. The second phasor of the fundamental current during the fault period is obtained by performing a full-wave Fourier transform operation based on real-time fault sampling data. Based on the second phasor and the switching information, the fault phase selection calculation is performed to determine the fault characteristic judgment result; Based on the fault characteristic determination results and the protection setting and control mechanism, a trip signal is generated.

[0010] Furthermore, the host device is also equipped with a secondary circuit display module; The aforementioned method for pre-commissioning secondary equipment in an intelligent substation further includes: The secondary circuit display module visualizes fault test parameters, protection setting and control mechanisms, fault simulation data, trip signals, current operating status data, and action reports.

[0011] An embodiment of the present invention also provides a pre-commissioning system for secondary equipment in an intelligent substation, comprising: a host device and a real-time digital simulation device cabinet; wherein, the host device is equipped with a virtual protection device; The host device is used to respond to the user's simulation setting operation, set the fault test parameters corresponding to the simulation model of the primary system of the intelligent substation, and set the protection setting control mechanism of the virtual protection device; and send the fault test parameters to the real-time digital simulation device cabinet. The real-time digital simulation device cabinet is used to drive the intelligent substation primary system simulation model to perform fault simulation based on the fault test parameters, generate fault simulation data, generate measurement and control data messages based on the fault simulation data, and send the measurement and control data messages to the host device. The host device is also used to parse the measurement and control data messages through the virtual protection device to obtain real-time sampling data and switch quantity information. According to the protection setting and control mechanism, it performs fault determination on the real-time sampling data and switch quantity information. If a fault is determined, it generates a trip signal according to the protection setting and control mechanism and transmits the trip signal to the real-time digital simulation device cabinet. The real-time digital simulation device cabinet is also used to drive the circuit breaker in the primary system simulation model of the intelligent substation to complete the tripping action according to the tripping signal, so as to realize the fault clearing of the primary system simulation model of the intelligent substation. After the fault is cleared, the current operating status data of the primary system simulation model of the intelligent substation is generated and the current operating status data is sent back to the virtual protection device. The host device is also used to parse the operating status data through the virtual protection device and generate a protection action report.

[0012] Furthermore, it also includes: switches; The real-time digital simulation device cabinet sends measurement and control data packets to the local area network via a switch, so that the virtual protection device can capture the measurement and control data packets from the local area network.

[0013] Furthermore, the host device is equipped with a secondary circuit display module; The host device is also used to visualize fault test parameters, protection setting and control mechanisms, fault simulation data, trip signals, current operating status data and action reports through the secondary circuit display module.

[0014] Furthermore, the real-time digital simulation device cabinet includes a network interface board; the network interface board is equipped with a sampling value communication module and a switch quantity communication module; The real-time digital simulation device cabinet is also used to convert analog current data into sampled value messages through a sampled value communication module, convert switch status information into switch message messages through a switch communication module, and use the sampled value messages and switch messages as measurement and control data messages.

[0015] The following benefits can be obtained by implementing the present invention: This invention provides a pre-commissioning method for secondary equipment in intelligent substations, applicable to host systems equipped with virtual protection devices. The core process includes simulation parameter configuration, fault simulation, data parsing, fault determination, closed-loop action, and report generation. Based on user operations, the system sets fault parameters for the primary system simulation model and the virtual protection device's setting and control mechanism, sending the fault parameters to the RTDS hardware cabinet, driving the simulation model to perform fault simulation and output fault analog data. The host system parses real-time fault data through the virtual protection device, obtaining sampled data and switch information, and completes fault determination based on the preset setting mechanism. After fault confirmation, the virtual protection device outputs a trip signal and sends it to the RTDS hardware cabinet, controlling the circuit breaker in the simulation model to trip and clear the fault. After fault clearance, the simulation model updates its operating status and sends back data. The virtual protection device parses and processes the status data, ultimately generating a protection action report, completing the entire pre-commissioning process.

[0016] This invention constructs a complete collaborative simulation and commissioning environment for primary and secondary equipment in substations. It uses digital simulation to complete the pre-commissioning of secondary equipment, verifying the effectiveness of protection fault identification and tripping response logic without requiring physical primary equipment. The entire closed-loop commissioning process realistically reproduces substation fault conditions, fully restoring the entire process of fault occurrence, protection action, fault clearing, and system status update. The output protection action report provides intuitive feedback on the commissioning results, facilitating the investigation of protection logic defects by staff. This significantly improves the accuracy and completeness of secondary equipment commissioning, effectively shortening the on-site commissioning cycle and reducing the cost and safety risks of physical commissioning. Attached Figure Description

[0017] To more clearly illustrate the technical solution of this application, the drawings used in the embodiments 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 from these drawings without creative effort.

[0018] Figure 1 This is a flowchart illustrating a pre-commissioning method for secondary equipment in an intelligent substation, provided in one embodiment of this application.

[0019] Figure 2 This is a schematic diagram of the structure of a pre-commissioning system for secondary equipment in an intelligent substation, provided in an embodiment of the present invention. Detailed Implementation

[0020] To make the objectives, technical solutions, and advantages of this application clearer, the technical solutions of this application will be clearly and completely described below with reference to the accompanying drawings of the embodiments. Obviously, the described embodiments are only some embodiments of this application, not all embodiments. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.

[0021] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application pertains; the terminology used herein is for the purpose of describing particular embodiments only and is not intended to limit the application; the terms “comprising” and “having”, and any variations thereof, in the specification, claims, and foregoing description of the drawings are intended to cover non-exclusive inclusion.

[0022] In the description of the embodiments of this application, technical terms such as "first" and "second" are used only to distinguish different objects and should not be construed as indicating or implying relative importance or implicitly specifying the number, specific order, or primary and secondary relationship of the indicated technical features. In the description of the embodiments of this application, "multiple" means two or more, unless otherwise explicitly defined.

[0023] In this document, the term "embodiment" means that a particular feature, structure, or characteristic described in connection with an embodiment may be included in at least one embodiment of this application. The appearance of this phrase in various places throughout the specification does not necessarily refer to the same embodiment, nor is it a separate or alternative embodiment mutually exclusive with other embodiments. It will be explicitly and implicitly understood by those skilled in the art that the embodiments described herein can be combined with other embodiments.

[0024] In the description of the embodiments in this application, the term "and / or" is merely a description of the relationship between related objects, indicating that three relationships can exist. For example, A and / or B can represent: A existing alone, A and B existing simultaneously, and B existing alone. Additionally, the character " / " in this document generally indicates that the preceding and following related objects have an "or" relationship.

[0025] In the description of the embodiments of this application, the term "multiple" refers to two or more (including two), similarly, "multiple sets" refers to two or more (including two sets), and "multiple pieces" refers to two or more (including two pieces).

[0026] In the description of the embodiments of this application, unless otherwise expressly specified and limited, technical terms such as "installation," "connection," "joining," and "fixing" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral part; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; they can refer to the internal communication of two components or the interaction between two components. For those skilled in the art, the specific meaning of the above terms in the embodiments of this application can be understood according to the specific circumstances.

[0027] See Figure 1 To address the issues of poor commissioning integrity and low efficiency in existing technologies, an embodiment of the present invention provides a pre-commissioning method for secondary equipment in an intelligent substation, comprising: S1. Respond to the user's simulation setting operation, set the fault test parameters corresponding to the primary system simulation model of the intelligent substation, and set the protection setting control mechanism of the virtual protection device; Specifically, the simulation settings for users are divided into two main configuration modules. The first is the setting of fault test parameters for the primary system simulation model of the intelligent substation. This operation relies on the workstation host connected to the RTDS hardware cabinet and is completed using the RSCAD software within the host. Staff can build a complete substation primary system model within the software, simultaneously customizing various fault test parameters such as single-phase grounding, phase-to-phase short circuit, fault location, and fault occurrence time. They can also build a circuit breaker control model and set and control simulation conditions such as switch opening and closing. The second is the setting of the protection setting and control mechanism on the virtual protection device side. First, various line and transformer protections are broken down into standardized independent algorithm modules. Then, the required protection functions are selected and configured as needed through a visual interface. Unselected modules do not participate in logical operations. At the same time, independent setting areas are divided for each protection segment, and setting parameters such as action threshold, delay, and setting coefficient are configured separately. Users can also customize output tripping logic such as phase-by-phase tripping and reclosing based on fault conditions. The entire customized configuration is stored in a local database. Each client configuration is independent and will not cause overwriting interference, thus forming a complete and standardized protection setting and control mechanism.

[0028] S2. Send the fault test parameters to the real-time digital simulation device cabinet so that the real-time digital simulation device cabinet can drive the intelligent substation primary system simulation model to perform fault simulation according to the fault test parameters, generate fault simulation data, and generate measurement and control data messages based on the fault simulation data. Preferably, the real-time digital simulation device cabinet includes a network interface board; the network interface board is equipped with a sampling value communication module and a switch quantity communication module; the fault analog quantity data includes current analog quantity data and switch status information; The real-time digital simulation device cabinet generates measurement and control data messages based on fault simulation data, including: The analog current data is converted into sampled value messages through the sampled value communication module; The switch status information is converted into switch messages through the switch communication module. Sampled value messages and switch quantity messages are used as measurement and control data messages.

[0029] Specifically, after configuring the fault test parameters and virtual protection setting mechanism, the system will send all fault test parameters to the RTDS hardware cabinet (i.e., the real-time digital simulation device cabinet). This cabinet is equipped with a processor board consisting of multiple digital signal processors. This board, as the core computing unit, can drive the intelligent substation primary system simulation model to complete fault simulation calculations based on the received fault test parameters, accurately simulating various substation fault conditions, and ultimately generating complete fault simulation data, specifically including current simulation data and the corresponding switch status information for circuit breakers and disconnectors. The real-time digital simulation device cabinet is equipped with a core network interface board, the GTNET board, which integrates a GTNET_SV sampling value communication module and a GTNET_GSE switch quantity communication module, respectively implementing message conversion functions for different data. The GTNET_SV sampling value communication module receives analog current data output from a primary system simulation model, converts it into SV sampling value messages conforming to the IEC61850-9-2 standard, and can be configured to match preset sampling rate, system frequency, and other parameters. The GTNET_GSE switch quantity communication module collects various switch status information from the simulation model and encapsulates it into standard GOOSE switch quantity messages. The sampling value messages and switch quantity messages are used together as measurement and control data messages, which are then transmitted to the switch via the cabinet communication link. The switch then connects to the local area network, providing complete data support for subsequent signal capture, data analysis, and fault diagnosis by virtual protection devices.

[0030] In this invention, after receiving the fault test parameters, the RTDS hardware cabinet can autonomously drive the primary system simulation model to complete high-precision fault simulation, simultaneously generating complete fault simulation quantities and equipment switch status data. Through the built-in dual-type communication module, the system can automatically convert the raw simulation data into SV and GOOSE messages conforming to the IEC61850 standard. These, along with the sampled value messages and switch quantity messages, constitute the measurement and control data messages. Standardized data transmission is achieved via a switch connected to the local area network, realizing the standardized, closed-loop output of the primary simulation data. This provides accurate, compliant, and complete data source support for subsequent core processes such as data parsing and fault diagnosis of the virtual protection device.

[0031] S3. Receive the measurement and control data messages generated by the real-time digital simulation device cabinet, and parse the measurement and control data messages through the virtual protection device to obtain real-time sampling data and switch quantity information; Preferably, the system receives measurement and control data messages generated by the real-time digital simulation device cabinet, parses the measurement and control data messages through a virtual protection device, and obtains real-time sampling data and switch quantity information, including: The system receives measurement and control data messages generated by the real-time digital simulation device cabinet, and uses a virtual protection device to parse the sampled value messages and switch quantity messages in the measurement and control data messages to obtain real-time sampled data and switch quantity information.

[0032] Specifically, the virtual protection device actively acquires measurement and control data messages, namely SV sampled value messages and GOOSE switch quantity messages, transmitted from the real-time digital simulation device cabinet on the local area network, completing the reception of both types of message signals. Based on this, the virtual protection device performs targeted parsing and processing on the two types of messages. It parses and converts the standard SV sampled value messages into current sampling data that the protection device can directly recognize; simultaneously, it parses and disassembles the GOOSE switch quantity messages, extracting the corresponding device switch quantity information, and finally outputs real-time sampled data and switch quantity information that can be used by the protection logic for judgment.

[0033] In this invention, the virtual protection device can automatically receive and parse standardized SV and GOOSE messages from within the local area network, converting the standardized communication messages output by the RTDS hardware cabinet into real-time sampled data and switch information that the protection logic can directly identify and call. This achieves the effective conversion of simulation communication data into data usable for protection operations, opens up the data interaction channel between the simulation equipment and the virtual protection device, and provides a reliable data foundation for the stable operation of core functions such as subsequent fault determination and protection operations.

[0034] S4. Based on the protection setting and control mechanism, perform fault determination on real-time sampled data and switch quantity information; Preferably, based on the protection setting and control mechanism, fault determination is performed on real-time sampled data and switch quantity information, including: Based on the switch input information, determine whether the protection function is allowed to be activated under the current operating condition; if it is determined that the protection function is not allowed to be activated, the fault determination is terminated directly. If it is determined that the protection function is allowed to be activated, then a half-wave Fourier transform operation is performed on the real-time sampled data to obtain the first phasor of the fundamental current. The change in the two-phase current difference of each group is calculated based on the first phasor, and the change in the two-phase current difference of each group is compared. The maximum value of the change in the two-phase current difference is taken as the global maximum phase current difference abrupt change. Fault determination is performed based on the protection setting and control mechanism, the global maximum phase current difference change, and the switching quantity information.

[0035] Specifically, the system first reads the parsed switch information to verify the current operating condition, thereby determining whether the protection function is ready to be activated. If it is determined that the protection function cannot be activated, the entire fault diagnosis process terminates directly. If the verification result indicates that the protection function can be activated, the system will retrieve real-time sampled data to perform a half-wave Fourier transform operation. The corresponding calculation formula is as follows: ; In the formula, N is the preset sampling rate. In the typical configuration of the pre-commissioning simulation of 220kV secondary equipment, N=80. This represents a sequence of instantaneous sampled values ​​of current or voltage; n represents the corresponding sampling point within the sampling period, calculated from... , These are the real and imaginary parts of the first complex fundamental component, respectively; then, using the conversion formula: ; Solve for amplitude With phase angle Thus, the first phasor of the fundamental current is obtained.

[0036] After obtaining the fundamental current phasor, the system uses the phase current difference change algorithm for calculation, and the calculation formula is as follows: ; In the formula It is the difference between the fundamental currents of phases A and B at the current time k; It is the difference between the two-phase currents at the corresponding moment in the previous cycle; This is the sudden change in the two-phase current difference during this cycle; calculated simultaneously. , Three sets of mutation values ​​were compared, and the maximum value was extracted. As the global maximum phase current difference abrupt change.

[0037] Finally, the fault determination is completed by combining the preset protection setting control mechanism, the global maximum phase current difference change, and the switching information. The judgment formula is as follows: ; In the formula The floating threshold intermediate quantity is from 1 to the earliest in the time sequence before the current time k. Each historical moment corresponds to , , It was obtained through numerical calculation; The preset parameter is a fixed threshold that can be adjusted. The value of this parameter is set when configuring the protection setting control mechanism in the early stage. In 220kV line protection, the secondary rated current In is used as the reference, and the setting range is 0.1In-0.3In, with a typical value of 0.2In. When In=1A, the corresponding actual current is 0.1A to 0.3A, and the commonly used setting value is 0.2A.

[0038] The global maximum phase current difference abrupt change calculated at the current time k The maximum sudden change is compared with the comprehensive threshold value on the right side of the formula. If the maximum sudden change is greater than the comprehensive threshold value, a fault is determined to have occurred in the system, and the sampling time k is locked as the fault occurrence time. If the maximum sudden change is less than or equal to the comprehensive threshold value, no fault is determined, and data is collected again at the next sampling time for cyclical calculation and judgment. The floating threshold can dynamically adjust the threshold according to the current fluctuations at historical times, suppressing numerical fluctuations caused by system oscillations and avoiding protection malfunctions.

[0039] In this invention, the device first verifies the protection commissioning conditions based on the switch quantity information. If the conditions are not met, the fault identification process is terminated directly. If the conditions are met, the fundamental component is quickly extracted using the half-wave Fourier algorithm. Then, the global maximum change value is obtained through the phase current difference change value algorithm. The fault identification is completed by combining the configurable fixed threshold and the dynamic floating threshold. The dynamic threshold can weaken the interference caused by system oscillation, effectively reduce the probability of protection maloperation, and achieve fast and reliable initial fault identification and fault moment locking.

[0040] S5. In the event of a fault, a trip signal is generated according to the protection setting and control mechanism and transmitted to the real-time digital simulation device cabinet, so that the real-time digital simulation device cabinet drives the circuit breaker in the primary system simulation model of the intelligent substation to complete the tripping action according to the trip signal, so as to realize the fault clearing of the primary system simulation model of the intelligent substation. After the fault is cleared, the current operating status data of the primary system simulation model of the intelligent substation is generated and the current operating status data is sent back to the virtual protection device. Preferably, in the event of a fault, a trip signal is generated according to the protection setting and control mechanism, including: If a fault is determined, the fault period is identified, and based on the fault period, the corresponding real-time fault sampling data is determined from the real-time sampling data. The second phasor of the fundamental current during the fault period is obtained by performing a full-wave Fourier transform operation based on real-time fault sampling data. Based on the second phasor and the switching information, the fault phase selection calculation is performed to determine the fault characteristic judgment result; Based on the fault characteristic determination results and the protection setting and control mechanism, a trip signal is generated.

[0041] Specifically, after the system determines that a fault has occurred, it first locks the corresponding sampling time as the fault period, and then extracts all real-time fault sampling data within the fault period for high-precision calculation processing. The processing adopts the full-wave Fourier transform algorithm, and the corresponding calculation formula is as follows: ; In the formula, N is the preset sampling rate, and in the typical configuration of the pre-commissioning simulation of 220kV secondary equipment, N=80; Represents a sequence of instantaneous current or voltage samples; k refers to the current time within the sampling sequence; m is the sampling point number within the fault period. , These are the real and imaginary parts of the second complex fundamental component, respectively; then, using the amplitude and phase angle conversion formulas: ; Solving for the precise amplitude With phase angle This allows us to obtain the second phasor of the fundamental current during the fault period. The full-wave Fourier algorithm covers the complete cycle of sampled data and has higher calculation accuracy than the half-wave Fourier algorithm, making it suitable for the detailed analysis needs after fault diagnosis.

[0042] The system calculates three sets of two-phase current difference abrupt changes using the second phasor. , , As input, combined with switch input information, fault phase selection calculations are performed to distinguish between ground faults and phase-to-phase faults to determine fault characteristics. If zero-sequence current is detected, it is determined to be a ground fault, and the grounding phase is identified using the following formula: ; In the formula, m is a preset setting coefficient, which is set during the protection setting and control mechanism configuration phase. The typical value range is 4~8. If the first condition is met, it is determined to be a phase A ground fault; if the second condition is met, it is determined to be a phase B ground fault; if the third condition is met, it is determined to be a phase C ground fault; if none of the conditions are met, it is determined to be a two-phase ground fault. If no zero-sequence current is detected, it is determined to be a phase-to-phase fault. The faulty phase is distinguished using the following formula: ; In the formula, n is also a preset setting coefficient, which is set during the protection setting and control mechanism configuration stage, and the normal value range is 4~8; if the first condition is met, it is determined that there is an AB phase-to-phase fault; if the second condition is met, it is determined that there is a BC phase-to-phase fault; if the third condition is met, it is determined that there is a CA phase-to-phase fault; if none of the conditions are met, it is determined that there is a three-phase short circuit. After the above calculation is completed, the fault characteristic judgment result is output.

[0043] The system retrieves the protection setting and control mechanism configured in the early stage. This mechanism includes independent settings for various protections, phase tripping logic, and priority rules for multiple protection actions. Taking 220kV line protection as an example, the fiber optic differential main protection directly trips three phases instantaneously. The distance and zero-sequence backup protections combine the fault phase selection results to perform phase tripping. When multiple protections act synchronously, they follow the timing rule of the main protection taking priority. The system combines the fault characteristic judgment results to match the corresponding output logic to generate a tripping signal.

[0044] After the trip signal is encapsulated in the standard GOOSE message format, it is sent to the switch via the local area network. The switch transmits the GOOSE message of the trip signal to the real-time digital simulation device cabinet. After receiving the message, the cabinet drives the circuit breaker in the internal intelligent substation primary system simulation model to perform the tripping operation and complete the fault clearing operation. After the fault clearing process is completed, the cabinet collects the updated line, circuit breaker, and disconnector operating parameters, generates new current operating status data for the intelligent substation primary system simulation model, and then sends the entire set of operating status data back to the virtual protection device for subsequent use in generating a complete protection action report.

[0045] In this invention, after diagnosing a fault, the device accurately pinpoints the fault period. It analyzes the fault sampling data using a high-precision full-wave Fourier transform algorithm to obtain a high-precision fundamental current phasor. Based on the corresponding current difference abrupt change phasor and setting coefficients, it accurately identifies the fault type and phase, clarifying the specific fault characteristics. The device, combined with a preset protection setting control mechanism, protection action priority, and tripping logic, matches the fault characteristics to generate a corresponding standardized GOOSE trip signal, which is transmitted to the RTDS hardware cabinet via a local area network to complete the circuit breaker tripping and fault clearing operations. After fault clearing, the simulation model updates the system operating status and completes data feedback, fully realizing accurate fault analysis, intelligent tripping control, and closed-loop updates of simulation operating conditions, effectively improving the accuracy of fault identification and the standardization and accuracy of protection action logic.

[0046] S6. Analyze the operating status data through the virtual protection device and generate a protection action report.

[0047] Specifically, after the real-time digital simulation device cabinet transmits the updated primary system operation status data after fault clearance back to the virtual protection device, the virtual protection device can comprehensively analyze and process the received full set of operation status data, automatically capturing and summarizing various core data information from the entire simulation test process to generate a standardized protection action report. This report covers complete and detailed protection action-related content, including the fault occurrence time, fault type and phase, current sampling data before and after the fault, protection activation time, type of protection activated and corresponding action delay, accurate fault phase selection result, actual trip output phase, GOOSE signal transmission time, status feedback data after circuit breaker action, all protection setting parameters configured for this simulation, communication operation status of SV and GOOSE signals throughout the process, final protection action conclusion, and records of all abnormal events generated during the test. The entire report is automatically generated by the device, eliminating the need for manual statistics and data entry. Test personnel can directly view the complete report content in the system, and the report can also be exported and saved, fully restoring the entire process of primary and secondary collaborative simulation debugging, including operating conditions and protection actions.

[0048] In this invention, the virtual protection device receives and analyzes the updated operational status data from the simulation model, automatically summarizing the core data from the entire simulation test process to generate a comprehensive and standardized protection action report. The report fully includes fault information, current sampling data, protection action sequence, tripping information, communication status, setting parameters, and abnormal events, among other key information across multiple dimensions. Data statistics and report generation are completed automatically throughout the entire process, requiring no manual intervention. Staff can view the report online at any time and export it for saving. The report fully reproduces the test conditions and protection action process of the primary and secondary co-simulations, providing comprehensive data support for simulation test result verification, protection logic analysis, and fault tracing.

[0049] Preferably, the secondary circuit display module visualizes the fault test parameters, protection setting and control mechanism, fault simulation data, trip signal, current operating status data, and action report.

[0050] Specifically, the secondary circuit display module is built upon the entire station's SCD file and operates as an auxiliary module supporting the complete closed-loop testing process. The module can visualize all content, including fault test parameters, protection setting and control mechanism configurations, simulated fault data, tripping signals issued by virtual protection, primary system current operating status data transmitted after fault clearing, and the final output protection action report. During operation, the module intuitively presents the complete transmission links of various data and signals between different devices, clearly demonstrating all virtual circuit connections within the secondary system. Simultaneously, it monitors the entire communication operation status of the secondary network in real time, continuously capturing the sending and receiving of SV and GOOSE messages, communication delays during message transmission, message loss, and other anomalies. If configuration problems such as virtual terminal configuration errors or dataset channel mismatches occur, or various communication faults occur, the fault location can be quickly pinpointed. By combining the visualized complete set of simulation test data with communication monitoring information, staff can efficiently complete the troubleshooting and verification of protection logic and communication link-related issues.

[0051] See Figure 2 This invention provides an intelligent substation secondary equipment pre-commissioning system, comprising: a host device and a real-time digital simulation device cabinet; wherein, the host device is equipped with a virtual protection device. The host device is used to respond to the user's simulation setting operation, set the fault test parameters corresponding to the simulation model of the primary system of the intelligent substation, and set the protection setting control mechanism of the virtual protection device; and send the fault test parameters to the real-time digital simulation device cabinet. The real-time digital simulation device cabinet is used to drive the intelligent substation primary system simulation model to perform fault simulation based on the fault test parameters, generate fault simulation data, generate measurement and control data messages based on the fault simulation data, and send the measurement and control data messages to the host device. The host device is also used to parse the measurement and control data messages through the virtual protection device to obtain real-time sampling data and switch quantity information. According to the protection setting and control mechanism, it performs fault determination on the real-time sampling data and switch quantity information. If a fault is determined, it generates a trip signal according to the protection setting and control mechanism and transmits the trip signal to the real-time digital simulation device cabinet. The real-time digital simulation device cabinet is also used to drive the circuit breaker in the primary system simulation model of the intelligent substation to complete the tripping action according to the tripping signal, so as to realize the fault clearing of the primary system simulation model of the intelligent substation. After the fault is cleared, the current operating status data of the primary system simulation model of the intelligent substation is generated and the current operating status data is sent back to the virtual protection device. The host device is also used to parse the operating status data through the virtual protection device and generate a protection action report.

[0052] Specifically, in a preferred embodiment of the present invention, the user's simulation setting operation is divided into two main configuration modules. The first is the setting of relevant fault test parameters for the primary system simulation model of the intelligent substation. This operation relies on the workstation host connected to the RTDS computer cabinet and is completed using RSCAD software within the host. Staff can build a complete substation primary system model within the software, simultaneously customizing various fault test parameters such as single-phase grounding, phase-to-phase short circuit, fault location, and fault occurrence time. They can also build a circuit breaker control model and set and control simulation conditions such as switch opening and closing. The second is the setting of the protection setting and control mechanism on the virtual protection device side. First, various line and transformer protections are broken down into standardized independent algorithm modules. Then, the required protection functions are selected and configured as needed through a visual interface. Unselected modules do not participate in logical operations. Simultaneously, independent setting areas are divided for each protection segment, and setting parameters such as action threshold, delay, and setting coefficient are configured separately. Users can also customize output tripping logic such as phase-by-phase tripping and reclosing based on fault conditions. The entire customized configuration is stored in a local database. Each client configuration is independent and will not cause overwriting interference, thus forming a complete and standardized protection setting and control mechanism.

[0053] Preferably, the real-time digital simulation device cabinet includes a network interface board; the network interface board is equipped with a sampling value communication module and a switch quantity communication module; the fault analog quantity data includes current analog quantity data and switch status information; The real-time digital simulation device cabinet generates measurement and control data messages based on fault simulation data, including: The analog current data is converted into sampled value messages through the sampled value communication module; The switch status information is converted into switch messages through the switch communication module. Sampled value messages and switch quantity messages are used as measurement and control data messages.

[0054] Specifically, after configuring the fault test parameters and virtual protection setting mechanism, the system will send all fault test parameters to the RTDS hardware cabinet (i.e., the real-time digital simulation device cabinet). This cabinet is equipped with a processor board consisting of multiple digital signal processors. This board, as the core computing unit, can drive the intelligent substation primary system simulation model to complete fault simulation calculations based on the received fault test parameters, accurately simulating various substation fault conditions, and ultimately generating complete fault simulation data, specifically including current simulation data and the corresponding switch status information for circuit breakers and disconnectors. The real-time digital simulation device cabinet is equipped with a core network interface board, the GTNET board, which integrates a GTNET_SV sampling value communication module and a GTNET_GSE switch quantity communication module, respectively implementing message conversion functions for different data. The GTNET_SV sampling value communication module receives analog current data output from a primary system simulation model, converts it into SV sampling value messages conforming to the IEC61850-9-2 standard, and can be configured to match preset sampling rate, system frequency, and other parameters. The GTNET_GSE switch quantity communication module collects various switch status information from the simulation model and encapsulates it into standard GOOSE switch quantity messages. The sampling value messages and switch quantity messages are used together as measurement and control data messages, which are then transmitted to the switch via the cabinet communication link. The switch then connects to the local area network, providing complete data support for subsequent signal capture, data analysis, and fault diagnosis by virtual protection devices.

[0055] In this invention, after receiving the fault test parameters, the RTDS hardware cabinet can autonomously drive the primary system simulation model to complete high-precision fault simulation, simultaneously generating complete fault simulation quantities and equipment switch status data. Through the built-in dual-type communication module, the system can automatically convert the raw simulation data into SV and GOOSE messages conforming to the IEC61850 standard. These, along with the sampled value messages and switch quantity messages, constitute the measurement and control data messages. Standardized data transmission is achieved via a switch connected to the local area network, realizing the standardized, closed-loop output of the primary simulation data. This provides accurate, compliant, and complete data source support for subsequent core processes such as data parsing and fault diagnosis of the virtual protection device.

[0056] Preferably, the system receives measurement and control data messages generated by the real-time digital simulation device cabinet, parses the measurement and control data messages through a virtual protection device, and obtains real-time sampling data and switch quantity information, including: The system receives measurement and control data messages generated by the real-time digital simulation device cabinet, and uses a virtual protection device to parse the sampled value messages and switch quantity messages in the measurement and control data messages to obtain real-time sampled data and switch quantity information.

[0057] Specifically, the virtual protection device actively acquires measurement and control data messages, namely SV sampled value messages and GOOSE switch quantity messages, transmitted from the real-time digital simulation device cabinet on the local area network, completing the reception of both types of message signals. Based on this, the virtual protection device performs targeted parsing and processing on the two types of messages. It parses and converts the standard SV sampled value messages into current sampling data that the protection device can directly recognize; simultaneously, it parses and disassembles the GOOSE switch quantity messages, extracting the corresponding device switch quantity information, and finally outputs real-time sampled data and switch quantity information that can be used by the protection logic for judgment.

[0058] In this invention, the virtual protection device can automatically receive and parse standardized SV and GOOSE messages from within the local area network, converting the standardized communication messages output by the RTDS hardware cabinet into real-time sampled data and switch information that the protection logic can directly identify and call. This achieves the effective conversion of simulation communication data into data usable for protection operations, opens up the data interaction channel between the simulation equipment and the virtual protection device, and provides a reliable data foundation for the stable operation of core functions such as subsequent fault determination and protection operations.

[0059] Preferably, based on the protection setting and control mechanism, fault determination is performed on real-time sampled data and switch quantity information, including: Based on the switch input information, determine whether the protection function is allowed to be activated under the current operating condition; if it is determined that the protection function is not allowed to be activated, the fault determination is terminated directly. If it is determined that the protection function is allowed to be activated, then a half-wave Fourier transform operation is performed on the real-time sampled data to obtain the first phasor of the fundamental current. The change in the two-phase current difference of each group is calculated based on the first phasor, and the change in the two-phase current difference of each group is compared. The maximum value of the change in the two-phase current difference is taken as the global maximum phase current difference abrupt change. Fault determination is performed based on the protection setting and control mechanism, the global maximum phase current difference change, and the switching quantity information.

[0060] Specifically, the system first reads the parsed switch information to verify the current operating condition, thereby determining whether the protection function is ready to be activated. If it is determined that the protection function cannot be activated, the entire fault diagnosis process terminates directly. If the verification result indicates that the protection function can be activated, the system will retrieve real-time sampled data to perform a half-wave Fourier transform operation. The corresponding calculation formula is as follows: ; In the formula, N is the preset sampling rate. In the typical configuration of the pre-commissioning simulation of 220kV secondary equipment, N=80. Represents a sequence of instantaneous current or voltage samples; k refers to the current time within the sampling sequence; m is the sampling point number within the fault period. , These are the real and imaginary parts of the second complex fundamental component, respectively; then, using the conversion formula: ; Solve for amplitude With phase angle Thus, the first phasor of the fundamental current is obtained.

[0061] After obtaining the fundamental current phasor, the system uses the phase current difference change algorithm for calculation, and the calculation formula is as follows: ; In the formula It is the difference between the fundamental currents of phases A and B at the current time k; It is the difference between the two-phase currents at the corresponding moment in the previous cycle; This is the sudden change in the two-phase current difference during this cycle; calculated simultaneously. , Three sets of mutation values ​​were compared, and the maximum value was extracted. As the global maximum phase current difference abrupt change.

[0062] Finally, the fault determination is completed by combining the preset protection setting control mechanism, the global maximum phase current difference change, and the switching information. The judgment formula is as follows: ; In the formula The floating threshold intermediate quantity is from 1 to the earliest in the time sequence before the current time k. Each historical moment corresponds to , , It was obtained through numerical calculation; The preset parameter is a fixed threshold that can be adjusted. The value of this parameter is set when configuring the protection setting control mechanism in the early stage. In 220kV line protection, the secondary rated current In is used as the reference, and the setting range is 0.1In-0.3In, with a typical value of 0.2In. When In=1A, the corresponding actual current is 0.1A to 0.3A, and the commonly used setting value is 0.2A.

[0063] The global maximum phase current difference abrupt change calculated at the current time k The maximum sudden change is compared with the comprehensive threshold value on the right side of the formula. If the maximum sudden change is greater than the comprehensive threshold value, a fault is determined to have occurred in the system, and the sampling time k is locked as the fault occurrence time. If the maximum sudden change is less than or equal to the comprehensive threshold value, no fault is determined, and data is collected again at the next sampling time for cyclical calculation and judgment. The floating threshold can dynamically adjust the threshold according to the current fluctuations at historical times, suppressing numerical fluctuations caused by system oscillations and avoiding protection malfunctions.

[0064] In this invention, the device first verifies the protection commissioning conditions based on the switch quantity information. If the conditions are not met, the fault identification process is terminated directly. If the conditions are met, the fundamental component is quickly extracted using the half-wave Fourier algorithm. Then, the global maximum change value is obtained through the phase current difference change value algorithm. The fault identification is completed by combining the configurable fixed threshold and the dynamic floating threshold. The dynamic threshold can weaken the interference caused by system oscillation, effectively reduce the probability of protection maloperation, and achieve fast and reliable initial fault identification and fault moment locking.

[0065] Preferably, in the event of a fault, a trip signal is generated according to the protection setting and control mechanism, including: If a fault is determined, the fault period is identified, and based on the fault period, the corresponding real-time fault sampling data is determined from the real-time sampling data. The second phasor of the fundamental current during the fault period is obtained by performing a full-wave Fourier transform operation based on real-time fault sampling data. Based on the second phasor and the switching information, the fault phase selection calculation is performed to determine the fault characteristic judgment result; Based on the fault characteristic determination results and the protection setting and control mechanism, a trip signal is generated.

[0066] Specifically, after the system determines that a fault has occurred, it first locks the corresponding sampling time as the fault period, and then extracts all real-time fault sampling data within the fault period for high-precision calculation processing. The processing adopts the full-wave Fourier transform algorithm, and the corresponding calculation formula is as follows: ; In the formula, N is the preset sampling rate, and in the typical configuration of the pre-commissioning simulation of 220kV secondary equipment, N=80; Represents a sequence of instantaneous current or voltage samples; k refers to the current time within the sampling sequence; m is the sampling point number within the fault period. , These are the real and imaginary parts of the second complex fundamental component, respectively; then, using the amplitude and phase angle conversion formulas: ; Solving for the precise amplitude With phase angle This allows us to obtain the second phasor of the fundamental current during the fault period. The full-wave Fourier algorithm covers the complete cycle of sampled data and has higher calculation accuracy than the half-wave Fourier algorithm, making it suitable for the detailed analysis needs after fault diagnosis.

[0067] The system calculates three sets of two-phase current difference abrupt changes using the second phasor. , , As input, combined with switch input information, fault phase selection calculations are performed to distinguish between ground faults and phase-to-phase faults to determine fault characteristics. If zero-sequence current is detected, it is determined to be a ground fault, and the grounding phase is identified using the following formula: ; In the formula, m is a preset setting coefficient, which is set during the protection setting and control mechanism configuration phase. The typical value range is 4~8. If the first condition is met, it is determined to be a phase A ground fault; if the second condition is met, it is determined to be a phase B ground fault; if the third condition is met, it is determined to be a phase C ground fault; if none of the conditions are met, it is determined to be a two-phase ground fault. If no zero-sequence current is detected, it is determined to be a phase-to-phase fault. The faulty phase is distinguished using the following formula: ; In the formula, n is also a preset setting coefficient, which is set during the protection setting and control mechanism configuration stage, and the normal value range is 4~8; if the first condition is met, it is determined that there is an AB phase-to-phase fault; if the second condition is met, it is determined that there is a BC phase-to-phase fault; if the third condition is met, it is determined that there is a CA phase-to-phase fault; if none of the conditions are met, it is determined that there is a three-phase short circuit. After the above calculation is completed, the fault characteristic judgment result is output.

[0068] The system retrieves the protection setting and control mechanism configured in the early stage. This mechanism includes independent settings for various protections, phase tripping logic, and priority rules for multiple protection actions. Taking 220kV line protection as an example, the fiber optic differential main protection directly trips three phases instantaneously. The distance and zero-sequence backup protections combine the fault phase selection results to perform phase tripping. When multiple protections act synchronously, they follow the timing rule of the main protection taking priority. The system combines the fault characteristic judgment results to match the corresponding output logic to generate a tripping signal.

[0069] After the trip signal is encapsulated in the standard GOOSE message format, it is sent to the switch via the local area network. The switch transmits the GOOSE message of the trip signal to the real-time digital simulation device cabinet. After receiving the message, the cabinet drives the circuit breaker in the internal intelligent substation primary system simulation model to perform the tripping operation and complete the fault clearing operation. After the fault clearing process is completed, the cabinet collects the updated line, circuit breaker, and disconnector operating parameters, generates new current operating status data for the intelligent substation primary system simulation model, and then sends the entire set of operating status data back to the virtual protection device for subsequent use in generating a complete protection action report.

[0070] In this invention, after diagnosing a fault, the device accurately pinpoints the fault period. It analyzes the fault sampling data using a high-precision full-wave Fourier transform algorithm to obtain a high-precision fundamental current phasor. Based on the corresponding current difference abrupt change phasor and setting coefficients, it accurately identifies the fault type and phase, clarifying the specific fault characteristics. The device, combined with a preset protection setting control mechanism, protection action priority, and tripping logic, matches the fault characteristics to generate a corresponding standardized GOOSE trip signal, which is transmitted to the RTDS hardware cabinet via a local area network to complete the circuit breaker tripping and fault clearing operations. After fault clearing, the simulation model updates the system operating status and completes data feedback, fully realizing accurate fault analysis, intelligent tripping control, and closed-loop updates of simulation operating conditions, effectively improving the accuracy of fault identification and the standardization and accuracy of protection action logic.

[0071] Specifically, after the real-time digital simulation device cabinet transmits the updated primary system operation status data after fault clearance back to the virtual protection device, the virtual protection device can comprehensively analyze and process the received full set of operation status data, automatically capturing and summarizing various core data information from the entire simulation test process to generate a standardized protection action report. This report covers complete and detailed protection action-related content, including the fault occurrence time, fault type and phase, current sampling data before and after the fault, protection activation time, type of protection activated and corresponding action delay, accurate fault phase selection result, actual trip output phase, GOOSE signal transmission time, status feedback data after circuit breaker action, all protection setting parameters configured for this simulation, communication operation status of SV and GOOSE signals throughout the process, final protection action conclusion, and records of all abnormal events generated during the test. The entire report is automatically generated by the device, eliminating the need for manual statistics and data entry. Test personnel can directly view the complete report content in the system, and the report can also be exported and saved, fully restoring the entire process of primary and secondary collaborative simulation debugging, including operating conditions and protection actions.

[0072] In this invention, the virtual protection device receives and analyzes the updated operational status data from the simulation model, automatically summarizing the core data from the entire simulation test process to generate a comprehensive and standardized protection action report. The report fully includes fault information, current sampling data, protection action sequence, tripping information, communication status, setting parameters, and abnormal events, among other key information across multiple dimensions. Data statistics and report generation are completed automatically throughout the entire process, requiring no manual intervention. Staff can view the report online at any time and export it for saving. The report fully reproduces the test conditions and protection action process of the primary and secondary co-simulations, providing comprehensive data support for simulation test result verification, protection logic analysis, and fault tracing.

[0073] Preferably, the host device is equipped with a secondary circuit display module; The host device is also used to visualize fault test parameters, protection setting and control mechanisms, fault simulation data, trip signals, current operating status data and action reports through the secondary circuit display module.

[0074] Specifically, the secondary circuit display module is built upon the entire station's SCD file and operates as an auxiliary module supporting the complete closed-loop testing process. The module can visualize all content, including fault test parameters, protection setting and control mechanism configurations, simulated fault data, tripping signals issued by virtual protection, primary system current operating status data transmitted after fault clearing, and the final output protection action report. During operation, the module intuitively presents the complete transmission links of various data and signals between different devices, clearly demonstrating all virtual circuit connections within the secondary system. Simultaneously, it monitors the entire communication operation status of the secondary network in real time, continuously capturing the sending and receiving of SV and GOOSE messages, communication delays during message transmission, message loss, and other anomalies. If configuration problems such as virtual terminal configuration errors or dataset channel mismatches occur, or various communication faults occur, the fault location can be quickly pinpointed. By combining the visualized complete set of simulation test data with communication monitoring information, staff can efficiently complete the troubleshooting and verification of protection logic and communication link-related issues.

[0075] It is understood that the above system embodiments correspond to the method embodiments of the present invention, and can implement the intelligent substation secondary equipment pre-commissioning method provided by any of the above method embodiments of the present invention.

[0076] It should be noted that the system embodiments described above are merely illustrative, and some or all of the devices can be selected to achieve the purpose of this embodiment according to actual needs. Furthermore, in the accompanying drawings of the system embodiments provided by this invention, the connection relationships between devices indicate that they have communication connections, which can specifically be implemented as one or more communication buses or signal lines. Those skilled in the art can understand and implement this without any creative effort.

[0077] The above description represents the preferred embodiments of the present invention. It should be noted that those skilled in the art can make various improvements and modifications without departing from the principles of the present invention, and these improvements and modifications are also considered to be within the scope of protection of the present invention.

Claims

1. A pre-commissioning method for secondary equipment in an intelligent substation, characterized in that, Applicable to host devices, wherein the host devices are equipped with virtual protection devices; The pre-commissioning method for secondary equipment in the intelligent substation includes: Responding to the user's simulation setting operation, the system sets the corresponding fault test parameters for the primary system simulation model of the intelligent substation, and sets the protection setting control mechanism for the virtual protection device; The fault test parameters are sent to the real-time digital simulation device cabinet, so that the real-time digital simulation device cabinet drives the intelligent substation primary system simulation model to perform fault simulation according to the fault test parameters, generates fault simulation data, and generates measurement and control data messages based on the fault simulation data. Receive the measurement and control data messages generated by the real-time digital simulation device cabinet, and parse the measurement and control data messages through the virtual protection device to obtain real-time sampling data and switch quantity information; Based on the protection setting and control mechanism, fault determination is performed on real-time sampled data and switch quantity information; In the event of a fault, a trip signal is generated according to the protection setting and control mechanism and transmitted to the real-time digital simulation device cabinet. The real-time digital simulation device cabinet then drives the circuit breaker in the primary system simulation model of the intelligent substation to perform a tripping action based on the trip signal, thereby clearing the fault in the primary system simulation model of the intelligent substation. After the fault is cleared, the current operating status data of the primary system simulation model of the intelligent substation is generated and transmitted back to the virtual protection device. The virtual protection device analyzes the operating status data and generates protection action reports.

2. The pre-commissioning method for secondary equipment in an intelligent substation as described in claim 1, characterized in that, The real-time digital simulation device cabinet includes a network interface board; the network interface board is equipped with a sampling value communication module and a switch quantity communication module. The fault simulation data includes current simulation data and switch status information; The real-time digital simulation device cabinet generates measurement and control data messages based on fault simulation data, including: The analog current data is converted into sampled value messages through the sampled value communication module; The switch status information is converted into switch messages through the switch communication module. Sampled value messages and switch quantity messages are used as measurement and control data messages.

3. The pre-commissioning method for secondary equipment in an intelligent substation as described in claim 2, characterized in that, The system receives measurement and control data messages generated by the real-time digital simulation device cabinet, parses the data messages using a virtual protection device, and obtains real-time sampling data and switch quantity information, including: The system receives measurement and control data messages generated by the real-time digital simulation device cabinet, and uses a virtual protection device to parse the sampled value messages and switch quantity messages in the measurement and control data messages to obtain real-time sampled data and switch quantity information.

4. The pre-commissioning method for secondary equipment in an intelligent substation as described in claim 3, characterized in that, Based on the aforementioned protection setting and control mechanism, fault determination is performed on real-time sampled data and switch quantity information, including: Based on the switch input information, determine whether the protection function is allowed to be activated under the current operating condition; if it is determined that the protection function is not allowed to be activated, the fault determination is terminated directly. If it is determined that the protection function is allowed to be activated, then a half-wave Fourier transform operation is performed on the real-time sampled data to obtain the first phasor of the fundamental current. The change in the two-phase current difference of each group is calculated based on the first phasor, and the change in the two-phase current difference of each group is compared. The maximum value of the change in the two-phase current difference is taken as the global maximum phase current difference abrupt change. Fault determination is performed based on the protection setting and control mechanism, the global maximum phase current difference change, and the switching quantity information.

5. The pre-commissioning method for secondary equipment in an intelligent substation as described in claim 4, characterized in that, In the event of a fault, a trip signal is generated according to the aforementioned protection setting and control mechanism, including: If a fault is determined, the fault period is identified, and based on the fault period, the corresponding real-time fault sampling data is determined from the real-time sampling data. The second phasor of the fundamental current during the fault period is obtained by performing a full-wave Fourier transform operation based on real-time fault sampling data. Based on the second phasor and the switching information, the fault phase selection calculation is performed to determine the fault characteristic judgment result; Based on the fault characteristic determination results and the protection setting and control mechanism, a trip signal is generated.

6. The pre-commissioning method for secondary equipment in an intelligent substation as described in claim 5, characterized in that, The host device is also equipped with a secondary circuit display module; The aforementioned method for pre-commissioning secondary equipment in an intelligent substation further includes: The secondary circuit display module visualizes fault test parameters, protection setting and control mechanisms, fault simulation data, trip signals, current operating status data, and action reports.

7. A pre-commissioning system for secondary equipment in an intelligent substation, characterized in that, include: The host equipment and the real-time digital simulation device cabinet; wherein, the host equipment is equipped with a virtual protection device; The host device is used to respond to the user's simulation setting operation, set the fault test parameters corresponding to the simulation model of the primary system of the intelligent substation, and set the protection setting control mechanism of the virtual protection device; and send the fault test parameters to the real-time digital simulation device cabinet. The real-time digital simulation device cabinet is used to drive the intelligent substation primary system simulation model to perform fault simulation based on the fault test parameters, generate fault simulation data, generate measurement and control data messages based on the fault simulation data, and send the measurement and control data messages to the host device. The host device is also used to parse the measurement and control data messages through the virtual protection device to obtain real-time sampling data and switch quantity information. According to the protection setting and control mechanism, it performs fault determination on the real-time sampling data and switch quantity information. If a fault is determined, it generates a trip signal according to the protection setting and control mechanism and transmits the trip signal to the real-time digital simulation device cabinet. The real-time digital simulation device cabinet is also used to drive the circuit breaker in the primary system simulation model of the intelligent substation to complete the tripping action according to the tripping signal, so as to realize the fault clearing of the primary system simulation model of the intelligent substation. After the fault is cleared, the current operating status data of the primary system simulation model of the intelligent substation is generated and the current operating status data is sent back to the virtual protection device. The host device is also used to parse the operating status data through the virtual protection device and generate a protection action report.

8. The intelligent substation secondary equipment pre-commissioning system as described in claim 7, characterized in that, Also includes: switch; The real-time digital simulation device cabinet sends measurement and control data packets to the local area network via a switch, so that the virtual protection device can capture the measurement and control data packets from the local area network.

9. The intelligent substation secondary equipment pre-commissioning system as described in claim 8, characterized in that, The host device is equipped with a secondary circuit display module; The host device is also used to visualize fault test parameters, protection setting and control mechanisms, fault simulation data, trip signals, current operating status data and action reports through the secondary circuit display module.

10. The intelligent substation secondary equipment pre-commissioning system as described in claim 9, characterized in that, The real-time digital simulation device cabinet includes a network interface board; the network interface board is equipped with a sampling value communication module and a switch quantity communication module. The real-time digital simulation device cabinet is also used to convert analog current data into sampled value messages through a sampled value communication module, convert switch status information into switch messages through a switch communication module, and use the sampled value messages and switch messages as measurement and control data messages.

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