Self-adaptive switching method, system and equipment for relay protection constant value region and medium

Abstract

The invention discloses a relay protection constant value area adaptive switching method, system and device and a medium, and the method comprises the steps: collecting initial power grid data to obtain characterization power grid data, carrying out the recognition to obtain a power grid operation mode, and screening out a candidate relay protection constant value area; performing verification and pre-verification to obtain a final relay protection constant value area and generate a corresponding initial constant value switching instruction, and performing verification and manual approval on the initial constant value switching instruction to obtain a final constant value switching instruction; after the final constant value switching instruction is issued, the communication state of the field device and the execution capacity of the final constant value switching instruction are evaluated, and a comprehensive evaluation report is generated. According to the method, the problems of low efficiency and insufficient adaptability of traditional manual switching are solved, the switching accuracy and safety are improved in a full-process closed-loop mode, the complication requirement of a power grid is met, the operation and maintenance compliance requirement is met, and the relay protection dynamic adaptability and the power grid safety level are improved in an assisted mode.

Description

TECHNICAL FIELD

[0001] The present application relates to the field of power systems and their automation, and in particular to a relay protection setting value area adaptive switching method, system, device and medium. BACKGROUND

[0002] Relay protection is the core link of ensuring the safe and stable operation of the power system, and the relay protection setting value area needs to be switched according to different operating modes of the power grid, such as normal power supply, maintenance load reduction, load peak, etc., to ensure that the protection device acts in various scenarios. With the expansion of the power grid, high proportion of new energy grid connection and complex operating mode, the traditional manual research and judgment and manual switching of the relay protection setting value area mode has been difficult to meet the requirements of the power grid for switching real-time, accuracy and reliability, and the research and application of adaptive switching technology of the relay protection setting value area has become an urgent demand in the field of power system automation.

[0003] At present, the switching of the relay protection setting value area mainly depends on the experience of the operation and maintenance personnel, and the switching efficiency is low and the relay protection setting value area is easily misselected due to human error, which may cause protection misoperation or refusal to operate and threaten the safety of the power grid. In addition, the matching of the relay protection setting value area lacks effective fusion of historical operation data and systematic verification of the candidate relay protection setting value area, such as reliability test and sensitivity test, which leads to insufficient adaptation of the relay protection setting value area to the actual operating conditions of the power grid, and the reliability is difficult to guarantee under complex operating conditions, and the protection efficiency cannot be fully utilized. SUMMARY

[0004] In view of the above existing problems, the present application is proposed.

[0005] Therefore, the present application provides a relay protection setting value area adaptive switching method, system, device and medium to solve the problems that the switching of the relay protection setting value area depends on manual experience operation, the efficiency is low and misselection is easy, which may cause protection misoperation or refusal to operate and threaten the safety of the power grid; and the matching of the relay protection setting value area cannot effectively fuse historical operation data and lacks systematic verification, which leads to insufficient adaptation to the actual operating conditions of the power grid and difficult to guarantee the reliability under complex operating conditions, and the protection efficiency cannot be fully utilized.

[0006] To solve the above technical problems, the present application provides the following technical solutions: In a first aspect, the present application provides a relay protection setting value area adaptive switching method, comprising: collecting initial power grid data and preprocessing the initial power grid data to obtain characteristic power grid data; matching the characteristic power grid data with a pre-stored standard operating mode template to identify the operating mode of the power grid, and selecting a candidate relay protection setting value area according to the identified operating mode of the power grid; The final relay protection setting range is obtained by verifying and pre-verifying the candidate relay protection setting range. The corresponding initial setting switching instruction is generated according to the final relay protection setting area, and the final setting switching instruction is obtained by verifying the initial setting switching instruction and manually approving it. After issuing the final setpoint switching command, the communication status of the field device and its ability to execute the final setpoint switching command are evaluated, and a comprehensive evaluation report is generated.

[0007] As a preferred embodiment of the adaptive switching method for relay protection setting areas described in this invention, the step of obtaining characteristic power grid data includes: Initial power grid data is collected, and the initial power grid data is processed by data completion and time alignment to obtain time-aligned data; The time-series aligned data is classified according to the physical variable type to obtain classified data; Data fusion is performed on the classified data belonging to the same physical variable to generate corresponding single physical variable data; Anomaly detection and cleaning are performed on the single physical variable data to obtain characteristic power grid data.

[0008] The beneficial effects of this preferred technical solution are as follows: by performing data completion and time alignment on the initial power grid data, the problems of missing data and inconsistent timing are solved, ensuring the effectiveness of timing-aligned data; by classifying and fusing data of the same variable according to the type of physical variable, the error of a single data source is reduced, and single physical variable data is generated; and by detecting anomalies and cleaning and removing interference data, the accuracy of characteristic power grid data is ensured, providing reliable data support for subsequent identification of power grid operation mode and selection of candidate relay protection setting areas.

[0009] As a preferred embodiment of the adaptive switching method for relay protection setting zones described in this invention, the step of identifying the power grid operating mode includes: Extract the power grid operation features from the characteristic power grid data, and normalize the power grid operation features to obtain normalized operation features; Pre-store standard operation mode templates, and calculate the distance result by comparing the normalized operation features with each of the standard operation mode templates; Based on the distance results, the power grid operation mode is identified through pattern matching and classification.

[0010] The beneficial effects of this preferred technical solution are as follows: First, power grid operation characteristics are extracted from the characteristic power grid data and normalized to eliminate the dimensional differences of different characteristics and ensure comparability; then, based on the pre-stored standard operation mode template, the current power grid operation mode is identified through template distance calculation and pattern matching classification, providing a reliable basis for the subsequent selection of candidate relay protection setting areas, and improving the accuracy and stability of operation mode identification.

[0011] As a preferred embodiment of the adaptive switching method for relay protection setting areas described in this invention, the step of screening candidate relay protection setting areas includes: Based on the power grid operation mode, extract the corresponding normalized operation characteristics and the relay protection setting range adapted to the corresponding standard operation mode template, and calculate the initial matching degree between the normalized operation characteristics and the relay protection setting range; Set a matching threshold and use the relay protection setting area where the initial matching degree exceeds the matching threshold as the preliminary candidate setting area; Collect historical scenario data corresponding to the current power grid operation mode, extract the actual application effect data of the preliminary candidate setting area in each historical scenario, and calculate the historical effect score; combine the historical effect score to perform a weighted correction on the initial matching degree of the preliminary candidate setting area to obtain the corrected matching degree; Constraint conflict verification is performed on the preliminary candidate value areas to obtain feasibility verification results, and a comprehensive score is calculated by combining the corrected matching degree and historical effect score to obtain the candidate value areas to be ranked. The candidate setting areas to be ranked are sorted from high to low according to the comprehensive score, and the top five candidate setting areas are selected to form the candidate relay protection setting areas.

[0012] The beneficial effects of this preferred technical solution are as follows: First, by combining the power grid operation mode and normalized operation characteristics, the initial matching degree of the adaptive relay protection setting area is calculated, and preliminary candidate setting areas are selected; then, the matching degree is corrected by using historical scenario application effect data, which is more in line with actual working conditions; subsequently, the top five candidates to be ranked are selected by constraint conflict verification and comprehensive scoring, which not only ensures the adaptability and feasibility of the candidates to be ranked, but also retains redundant alternatives, providing a basis for subsequent verification and final determination of the relay protection setting area.

[0013] As a preferred embodiment of the adaptive switching method for relay protection setting area described in this invention, the step of obtaining the final relay protection setting area includes: A verification benchmark model is constructed, and the candidate relay protection setting area is verified according to the verification benchmark model to generate verification results; Based on the verification results, the candidate relay protection setting areas are pre-verified, a pre-verification report is generated, and the comprehensive risk value of each candidate relay protection setting area is calculated in conjunction with the verification results. A preset risk threshold is used to eliminate candidate relay protection setting areas whose comprehensive risk value exceeds the risk threshold, thereby obtaining candidate relay protection setting areas. The candidate relay protection setting areas are sorted from low to high according to their comprehensive risk values, and the candidate relay protection setting area with the highest ranking is selected as the final relay protection setting area.

[0014] The beneficial effects of this preferred technical solution are as follows: by constructing a verification benchmark model to verify the candidate setting area, a reliable basis is provided for subsequent evaluation; then, combined with the verification results, pre-verification is carried out and a comprehensive risk value is calculated to eliminate candidate relay protection setting areas that exceed the risk threshold, ensuring the safety of the selected range; finally, the candidate setting area with the lowest comprehensive risk value is selected as the final relay protection setting area, which can minimize the application risk of the setting area and improve the safety and stability of the overall switching method.

[0015] As a preferred embodiment of the adaptive switching method for relay protection setting zones described in this invention, the step of obtaining the final setting switching command includes: Generate the corresponding initial setting switching command based on the final relay protection setting area; The initial setpoint switching command is verified, and a verification result is generated; If the verification result is successful, the initial setting value switching instruction is submitted for manual approval. If the verification result is unsuccessful, the initial setting value switching instruction is modified according to the result category until the verification is successful and then submitted for manual approval. After the manual approval is successful, the final setting value switching instruction is obtained.

[0016] The beneficial effects of this preferred technical solution are as follows: the initial setting switching command is generated based on the final relay protection setting area, and the parameter deviation, format error and other problems are eliminated in advance through the verification of the initial setting switching command and the modification mechanism when it fails; combined with manual approval, the dual control of verification and manual approval is formed, which not only avoids the potential omissions of automatic verification, but also meets the compliance requirements of power operation and maintenance, provides a safety premise for the execution of field devices, and improves the compliance and execution safety of the overall switching method.

[0017] As a preferred embodiment of the adaptive switching method for relay protection setting zones described in this invention, the step of evaluating the communication status of the field device and its ability to execute the final setting switching command, and generating a comprehensive evaluation report, includes: After issuing the final setting switching command, the field devices are monitored in real time, and a communication status assessment result is generated; The execution progress of the field device in response to the final setpoint switching command is monitored synchronously, and an execution capability assessment result is generated. A comprehensive evaluation report is generated by combining the communication status evaluation results and the execution capability evaluation results.

[0018] The beneficial effects of this preferred technical solution are as follows: After the final setting switch command is issued, by monitoring the communication status of the field device and the execution progress of the final setting switch command in real time, two types of evaluation results are generated: communication status evaluation result and execution capability evaluation result. This ensures that the device status and the execution status of the final setting switch command are understood. By combining the two results, a comprehensive evaluation report is generated, which not only promptly detects communication anomalies or execution deviations, but also provides a basis for subsequent operation and maintenance optimization. This forms a closed-loop management of command issuance, execution monitoring, and result evaluation, ensuring the effective implementation of the switch command and improving the reliability and traceability of the overall method.

[0019] Secondly, the present invention provides a relay protection setting zone adaptive switching system, comprising: The data acquisition and preprocessing module is used to acquire initial power grid data and preprocess the initial power grid data to obtain characteristic power grid data. The operation mode identification module is used to identify the power grid operation mode by matching the characteristic power grid data with the pre-stored standard operation mode template; The setting range filtering module is used to filter out candidate relay protection setting ranges based on the identified power grid operation mode. The verification and pre-verification module is used to verify and pre-verify the candidate relay protection setting range to obtain the final relay protection setting range. The instruction generation and approval module is used to generate a corresponding initial setting switching instruction based on the final relay protection setting range, and to obtain the final setting switching instruction by verifying the initial setting switching instruction and manually approving it. The evaluation module is used to evaluate the communication status and execution capability of the field device after the final setting switching command is issued, and generate a comprehensive evaluation report.

[0020] Thirdly, the present invention provides an electronic device, comprising: Memory and processor; The memory is used to store computer-executable instructions, and the processor is used to execute the computer-executable instructions. When the computer-executable instructions are executed by the processor, they implement the steps of the adaptive switching method for relay protection setting zones.

[0021] Fourthly, the present invention provides a computer-readable storage medium storing computer-executable instructions that, when executed by a processor, implement the steps of the adaptive switching method for relay protection setting zones.

[0022] Compared with existing technologies, this invention solves the problems of low efficiency, error-proneness, and insufficient adaptability of traditional manual switching. It lays a reliable foundation through data preprocessing and power grid operation mode identification. Candidate relay protection setting areas are optimized and screened through verification and scoring. The final setting switching instruction is generated with dual control of verification and manual approval. After execution, the communication status and execution status are monitored to generate a comprehensive evaluation report. This not only improves the accuracy and safety of switching but also meets the requirements of operation and maintenance compliance, adapts to the complex needs of the power grid, and enhances the adaptability of relay protection and the level of power grid safety. Attached Figure Description

[0023] To more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings used in the following description of the embodiments will be briefly introduced. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0024] Figure 1 This is a schematic diagram of the overall process of the adaptive switching method for relay protection setting area according to an embodiment of the present invention. Detailed Implementation

[0025] To make the above-mentioned objects, features, and advantages of the present invention more apparent and understandable, specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments of the present invention, and not all of them. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the protection scope of the present invention.

[0026] Example 1, referring to Figure 1 As an embodiment of the present invention, an adaptive switching method for relay protection setting zones is provided, comprising: S100. Collect initial power grid data and preprocess the initial power grid data to obtain characteristic power grid data.

[0027] S200. Match the characteristic power grid data with the pre-stored standard operation mode template to identify the power grid operation mode, and select candidate relay protection setting areas based on the identified power grid operation mode.

[0028] S300. Verify and pre-verify the candidate relay protection setting range to obtain the final relay protection setting range.

[0029] S400: Generate the corresponding initial setting switching instruction according to the final relay protection setting area, and obtain the final setting switching instruction by verifying the initial setting switching instruction and manually approving it.

[0030] S500: After issuing the final setting switching command, assess the communication status of the field device and its ability to execute the final setting switching command, and generate a comprehensive evaluation report.

[0031] It should be noted that relay protection setting zone switching is a core component in ensuring the safe and stable operation of the power system. It needs to adapt to different grid operating modes, such as normal power supply, maintenance and load reduction, and peak load scenarios. Its accuracy and timeliness affect the operational precision of protection devices and are crucial to the grid's fault prevention effectiveness. Currently, with the continuous expansion of the power grid and the high proportion of new energy sources connected to the grid, operating modes are becoming increasingly complex. The traditional manual judgment and manual switching of setting zones has significant limitations: on the one hand, it relies on the experience of maintenance personnel, resulting in low switching efficiency and susceptibility to human error leading to incorrect selection of relay protection setting zones, causing protection malfunctions or failures to operate; on the other hand, it lacks systematic preprocessing of grid data and comprehensive verification of candidate setting zones, resulting in insufficient adaptability of relay protection setting zones to actual operating conditions, making it difficult to guarantee reliability under complex operating conditions.

[0032] Therefore, to address the issues of low efficiency, error-proneness, and poor adaptability of traditional switching modes, the S100-S500 steps first preprocess the initial power grid data to obtain characteristic power grid data, providing reliable data support for subsequent analysis; then, combined with the standard operating mode template, the power grid operating mode is identified and candidate relay protection setting areas are screened to achieve preliminary matching between the operating conditions and the relay protection setting areas; the final relay protection setting area is determined through verification and pre-verification to reduce application risks; the final setting switching instruction is generated through dual control of verification and manual approval, and a comprehensive report is generated, taking into account both compliance and security, forming a closed-loop management of data, decision-making, execution, and evaluation, providing a feasible path for adaptive switching of relay protection setting areas, and improving the power grid's defense capabilities and operational reliability.

[0033] Example 2, refer to Figure 1 As an embodiment of the present invention, based on the above embodiment, an adaptive switching method for relay protection setting zones is provided.

[0034] In this embodiment of the application, a 110kV urban power distribution network, including 3 main lines, 8 distribution transformers, 12 circuit breakers, and 6 sets of relay protection devices, is used as the application scenario. The specific implementation of the steps in S100, A1~A4, to obtain characteristic power grid data is as follows: A1. Collect initial power grid data, and perform data completion and time alignment processing on the initial power grid data to obtain time-aligned data.

[0035] Specifically, initial grid data such as three-phase voltage, phase current, active power, reactive power, distribution transformer oil temperature, circuit breaker opening and closing status, and relay protection device operation status of the 110kV main line are collected through different devices, such as the distribution network SCADA system, PMU device, and smart terminal. The sampling frequency is 1 minute / time.

[0036] To address the issue of missing initial power grid data, such as voltage data loss due to PMU communication interruption at a certain moment, linear interpolation methods, such as cubic spline interpolation, are used to fill in the missing data. The formula is as follows: in, This represents the spline function on the i-th segment; is the interpolation coefficient; t is the required interpolation time point, such as missing data points 5 seconds past the hour. Let be the start time of the i-th segment. For example, the effective values ​​of phase A voltage of line L1 at 9:00 and 9:02 are 110kV and 112kV, respectively. The missing value at 9:01 can be filled by cubic spline interpolation.

[0037] For timestamps from different devices, such as SCADA which collects data on the hour and PMU which collects data 10 seconds after the hour, they are uniformly aligned to the standard time axis to generate time-aligned data.

[0038] A2. Classify the time-series aligned data according to the physical variable type to obtain classified data.

[0039] Specifically, based on physical variable attributes, the data is divided into four categories: voltage (e.g., three-phase voltage of the main line), current (e.g., phase current of the main line), power (e.g., active power and reactive power), and equipment status (e.g., circuit breaker opening and closing status, transformer oil temperature, and relay protection device operating status). Each category is numbered according to the monitoring point, such as line L1 and transformer T2, forming classified data.

[0040] A3. Perform data fusion on the classified data that belong to the same physical variable to generate corresponding single physical variable data.

[0041] Specifically, for categorical data of the same physical variable, a similarity assessment is first performed, using the following formula: In the formula, Representative categorical data and The current similarity score; For physical variables The mean; For physical variables The average value. For example, the similarity score of current data between monitoring point 1 and monitoring point 2 on line L1. .

[0042] Then, a weighted fusion algorithm is used to determine the similarity. When the accuracy levels of monitoring points are the same, the arithmetic mean is directly taken; if the accuracy levels are different, the weights are inversely proportional to the accuracy levels; if the similarity... Regardless of whether the precision is the same, the weight of high-precision data is strengthened. That is, based on the original inverse proportion of precision, the weight of high-precision data is increased by 10%, for example, the weight ratio of 0.2 level to 0.5 level. Adjusted to If similarity This triggers a reliability check, prioritizing the use of high-precision equipment data, such as 0.2-level classification data, which is directly used as the single physical variable data.

[0043] For example, the current at monitoring point 1 of line L1 is 500A (0.2 level), and the current at monitoring point 2 is 510A (0.2 level). And with the same precision, the data for a single physical variable is... The voltage at monitoring point 1 of line L2 is 115kV (level 0.2), and the voltage at monitoring point 2 is 110kV (level 0.5). Original precision weight ratio After adjustment, it is: Single physical variable data is .

[0044] A4. Perform anomaly detection and cleaning on the single physical variable data to obtain characteristic power grid data.

[0045] Specifically, the 3σ rule combined with expert experience thresholds is used to detect anomalies: For single physical variable data such as voltage and current, the standard deviation σ of historical data is calculated; values ​​exceeding the mean ± 3σ are considered anomalies, such as a sudden drop in line voltage to 80kV, exceeding the reasonable range of 100-120kV. For single physical variable data such as equipment status, logical checks are performed; for example, the current should be close to 0 when the circuit breaker is open. If it reaches 100A, it is considered an anomaly. Anomaly data is replaced with the moving average of the three nearest points in time. If there are more than five consecutive anomalies, it is marked as a sensor fault and an alarm is triggered. Finally, characteristic power grid data containing 28 features is generated.

[0046] In an optional implementation, step S100 may also include a data timeliness marker, which involves attaching a low-weight label to historical data collected more than 5 minutes ago, reducing the impact weight during subsequent feature extraction, and avoiding historical data from interfering with the identification of the current power grid operation mode.

[0047] In another optional implementation, an edge computing node can be introduced in step S100. The steps are as follows: the preliminary processing of data completion and anomaly detection is completed locally at the substation, and only the cleaned single physical variable data, such as voltage deviation rate and current mutation value, is uploaded to the main station to reduce the amount of data transmission and improve the preprocessing efficiency.

[0048] In this embodiment of the application, step S200, the step of selecting candidate relay protection setting areas, includes B1 to B5: B1. Based on the power grid operation mode, extract the corresponding normalized operation characteristics and the relay protection setting area adapted to the corresponding standard operation mode template, and calculate the initial matching degree between the normalized operation characteristics and the relay protection setting area.

[0049] Specifically, the power grid operation mode is first identified through B1.1-B1.3, then the corresponding normalized operation characteristics and the corresponding relay protection setting range are extracted, and the initial matching degree is calculated.

[0050] The steps for identifying the power grid operating mode include B1.1 to B1.3: B1.1 Extract the power grid operation features from the characteristic power grid data, and normalize the power grid operation features to obtain normalized operation features.

[0051] Specifically, six power grid operation features are extracted from the characteristic power grid data; the min-max normalization method is used to uniformly map the feature values ​​to the [0,1] interval. For example, if the original range of the average line voltage is 100-120kV, and the voltage of line L1 at a certain moment is 110kV, the normalized value is ( Finally, a 6-dimensional normalized running feature vector is obtained, such as [0.5, 0.3, 0.6, 0.8, 0.7, 0.4].

[0052] B1.2. Pre-store standard operation mode templates, and calculate the distance between the normalized operation features and each of the standard operation mode templates to obtain the distance result.

[0053] Specifically, three types of standard operating mode templates are pre-stored: normal power supply template, maintenance and load reduction template, and peak load template, corresponding to the three operating conditions of normal power supply, maintenance and load reduction, and peak load in the 110kV distribution network. Each template contains six-dimensional standard normalized features, such as [0.5, 0.4, 0.5, 0.9, 0.6, 0.5] for the normal power supply template. The Manhattan distance method is used to calculate the distance between the current normalized operating feature and each template, using the following formula: in, This represents the Manhattan distance between the current normalized operating characteristics and the m-th template; Representing the Dimensional normalized operational characteristics, here This corresponds to 6 operational feature dimensions; Represents the m-th template. The value of each running characteristic.

[0054] For example, the current normalized running feature vector is , with normal power supply template The Manhattan distance is: The distances to the maintenance load reduction formwork and the peak load formwork are 1.2 and 0.8 respectively, resulting in the final distance results. .

[0055] B1.3. Based on the distance results, the power grid operation mode is identified through pattern matching classification.

[0056] Specifically, a distance threshold of 0.5 is set, and templates with a distance ≤ 0.5 are marked as candidate templates. Using the principle of maximum membership, the candidate template with the smallest distance is selected as the current power grid operation mode, i.e., normal power supply, and the identification confidence level is recorded. The formula is: Where C represents the identification confidence level. The minimum distance among the candidate templates is T, where T is the distance threshold. For example, the normal power supply template is a candidate template. , Substituting into the calculation, we get: .

[0057] The initial matching degree formula is: Where M is the initial matching degree, and D is the Manhattan distance between the current normalized operating characteristics and the relay protection setting zone template. .

[0058] For example, the Manhattan distance is The initial matching degree The initial matching degrees of the five relay protection setting zones were 0.85, 0.82, 0.78, 0.75, and 0.70, respectively.

[0059] B2. Set a matching threshold and use the relay protection setting area where the initial matching degree exceeds the matching threshold as the preliminary candidate setting area.

[0060] Specifically, the initial matching degree threshold is set to 0.75, and relay protection setting areas with an initial matching degree ≥ 0.75 are included in the preliminary candidate range. Based on the results of B1.3, three sets of relay protection setting areas with initial matching degrees of 0.85, 0.82, and 0.78 meet the requirements and are used as preliminary candidate setting areas for devices P1, P2, and P3, respectively. Two sets of relay protection setting areas with matching degrees of 0.75 and 0.70 are eliminated.

[0061] B3. Collect historical scenario data corresponding to the current power grid operation mode, extract the actual application effect data of the preliminary candidate setting area in each historical scenario, and calculate the historical effect score; combine the historical effect score to perform weighted correction on the initial matching degree of the preliminary candidate setting area to obtain the corrected matching degree.

[0062] Specifically, historical scenario data of the 110kV distribution network under normal power supply conditions over the past three months were collected. Actual application performance data of three preliminary candidate setting areas in various scenarios were extracted, including but not limited to three indicators: action accuracy, response delay, and adaptation stability, each with a maximum score of 10 points. The average performance score of each preliminary candidate setting area was calculated. For example, the P1 device's preliminary candidate setting area had an average action accuracy of 9.5 points, a response delay of 9.0 points, and an adaptation stability of 8.5 points across 60 scenarios, with a historical performance score A = (9.5 + 9.0 + 8.5) / 3 = 9.0 points. Similarly, the historical performance scores of the P2 and P3 devices' preliminary candidate setting areas were 8.5 points and 8.0 points, respectively. The historical performance score weight was set to 0.3, and the initial matching degree weight was set to 0.7. The corrected matching degree was calculated using the following formula: in, To correct the matching degree, A represents the historical performance score; such as the initial candidate setting area of ​​device P1. =0.85×0.7+9.0 / 10×0.3=0.595+0.27=0.865; the final corrected matching degrees of the three preliminary candidate value regions are 0.865, 0.825, and 0.796, respectively.

[0063] B4. Perform constraint conflict verification on the preliminary candidate value areas to obtain the feasibility verification results, and calculate the comprehensive score by combining the corrected matching degree and historical effect score to obtain the candidate value areas to be ranked.

[0064] Specifically, constraint conflict verification was performed on the three preliminary candidate setting areas. It was checked whether the protection range of each preliminary candidate setting area covered the corresponding line. For example, the protection range of the P1 device setting area needed to cover the entire length of line L1, and the verification showed no conflict. The operating time limit was also checked to ensure it coordinated with adjacent devices. For example, the operating time limit of P1 was 0.5s, while the adjacent P4 device's time limit was 1.0s, showing no coordination conflict. All three preliminary candidate setting areas passed the verification, and the feasibility verification results were all passed. A comprehensive scoring calculation rule was set, and the formula is: Where B is the comprehensive score and P is the feasibility score. If it passes, P is 10 points and if it fails, P is 0 points. For example, the comprehensive score of the preliminary candidate value setting area of ​​device P1 is B = 0.865×60 + 0.9×30 + 10×1 = 51.9 + 27 + 10 = 88.9 points. Finally, the comprehensive scores of the three preliminary candidate value setting areas are 88.9, 83.5 and 78.8 respectively, and the list of candidate value setting areas to be ranked is obtained.

[0065] B5. Sort the candidate setting areas to be sorted from high to low according to the comprehensive score, and select the top five candidate setting areas to be sorted to form the candidate relay protection setting areas.

[0066] Specifically, the candidate setting areas to be ranked are sorted from high to low according to the comprehensive score, such as P1: 88.9 > P2: 83.5 > P3: 78.8. Since there are only 3 preliminary candidate setting areas, which is less than 5, all of them are selected to form candidate relay protection setting areas, including 3 sets of candidate relay protection setting areas under normal power supply conditions corresponding to devices P1, P2, and P3.

[0067] In an optional implementation, step S200 can also include real-time operating condition fine-tuning. The steps are as follows: if there is temporary new energy access in the current power grid, such as L2 line accessing 2MW of distributed photovoltaic, then the new energy output ratio feature is added to B1.1 and expanded into a 7-dimensional normalized operating feature to improve the accuracy of operating mode identification and relay protection setting area matching.

[0068] In another optional implementation, step S200 can also adjust the threshold mechanism as follows: based on the magnitude of power grid load fluctuation, such as when the load fluctuation is >20%, the matching threshold of the initial matching degree is lowered to 0.7 to avoid insufficient number of candidate relay protection setting areas due to changes in operating conditions and to ensure screening redundancy.

[0069] In this embodiment of the application, step S300, the step of obtaining the final relay protection setting range, includes C1~C4: C1. Construct a verification benchmark model, and verify the candidate relay protection setting area according to the verification benchmark model to generate verification results.

[0070] Specifically, a verification benchmark model is constructed, comprising three verification modules: a short-circuit current verification module, a time-limit coordination verification module, and a reliability assessment module. The short-circuit current verification module sets a short-circuit current threshold based on the power flow calculation results of the distribution network. For example, the maximum three-phase short-circuit current of line L1 is 20kA. It verifies whether the instantaneous overcurrent protection settings in the candidate relay protection setting area meet the requirements for reliable operation and non-overlapping, i.e., the instantaneous overcurrent protection setting ≤ 1.2 × the maximum short-circuit current. The time-limit coordination verification module uses a time difference ≥ 0.3s between adjacent devices as a benchmark. For example, the time difference between P1 and P4 must be ≥ 0.3s. It verifies whether the overcurrent protection time limits in the candidate setting area conform to the tiered coordination principle. The reliability assessment module incorporates historical statistical data such as the annual average number of faults and the probability of protection failure to operate, and sets a reliability threshold, such as a failure-to-operate probability ≤ 0.01 times / year.

[0071] The verification results for the setting areas of the three candidate relay protection systems are as follows: The instantaneous overcurrent setting of candidate relay protection P1 is 22kA≤24kA, and the time difference with P4 is 0.5s≥0.3s, with a failure to operate probability of 0.008 times / year. Therefore, the short-circuit current verification, time-limit coordination and reliability have all passed. P2 candidate relay protection setting range: instantaneous overcurrent setting 23kA≤24kA, time difference with P4 0.4s≥0.3s, failure to operate probability 0.012 times / year, slightly exceeding the threshold, so short circuit current verification, time limit coordination and reliability all pass; P3 candidate relay protection setting range: instantaneous overcurrent setting 24kA≤24kA, time difference with P4 0.2s<0.3s, failure to operate probability 0.009 times / year, so short circuit current verification and reliability pass, but time limit coordination fails.

[0072] C2. Based on the verification results, pre-verify the candidate relay protection setting areas, generate a pre-verification report, and calculate the comprehensive risk value of each candidate relay protection setting area in conjunction with the verification results.

[0073] Specifically, the candidate relay protection setting areas were pre-verified using the PSCAD / EMTDC simulation platform. Ten typical fault scenarios were simulated, including single-phase grounding on line L1 and three-phase short circuit on line L2. The response time and fault isolation range of the candidate relay protection setting areas were recorded, and a pre-verification report was generated. For example, if P1 operated correctly in eight scenarios with a response time ≤ 0.2s, and P3 caused over-level operation in two scenarios due to timing coordination issues, the comprehensive risk value was calculated based on the verification results and the pre-verification report. The formula is: in, To mitigate the risk of accidental activation, To avoid the risk of action, To accommodate conflict risks; risk weighting Calculation results: P1: , , , P2: , , , P3: , , , .

[0074] C3. Preset a risk threshold, and eliminate candidate relay protection setting areas whose comprehensive risk value exceeds the risk threshold to obtain candidate relay protection setting areas.

[0075] Specifically, based on the safety requirements of the 110kV distribution network under normal power supply conditions, a risk threshold is preset. The overall risk value The candidate relay protection setting area is retained as the alternative relay protection setting area: P1 P2 Those meeting the requirements are included in the shortlist; P3 is excluded. .

[0076] C4. Sort the candidate relay protection setting areas from low to high according to the comprehensive risk value, and select the candidate relay protection setting area with the highest ranking as the final relay protection setting area.

[0077] Specifically, the candidate relay protection setting areas are sorted from low to high according to their comprehensive risk values: P1 is 0.034 > P2 is 0.056. The normal power supply condition setting area corresponding to the P1 device, which ranks first, is selected as the final relay protection setting area.

[0078] In an optional implementation, real-time simulation verification can also be introduced in step S300. The steps are as follows: add a digital twin real-time simulation module to C1, and update the verification benchmark model according to the current real-time state of the power grid, such as load fluctuations and new energy output, to improve the timeliness of verification.

[0079] In another optional implementation, step S300 can also adjust the risk weight, as follows: when the distribution network connects to new energy sources, such as a 2MW photovoltaic power plant on line L2, the risk weight will be adjusted. Weight The threshold has been raised from 0.2 to 0.3 to strengthen the management and control of protection and coordination risks caused by the access of new energy sources.

[0080] In this embodiment of the application, step S400, the step of obtaining the final setpoint switching instruction, includes D1~D3: D1. Generate the corresponding initial setting switching command according to the final relay protection setting area.

[0081] Specifically, an initial setting switching command is generated based on the final relay protection setting area of ​​device P1. The initial setting switching command includes, but is not limited to, the following information: Operating object: Relay protection device P1 (No.: P1-110kV-L1); Setting zone code: #001 (normal power supply condition setting zone); Setting parameters: instantaneous overcurrent setting 22kA, overcurrent action time 0.5s, zero-sequence protection threshold 5A, etc.; Operation time window: The handover is scheduled to be carried out from 03:00 to 04:00 the next day (during the off-peak period of power grid load).

[0082] D2. Verify the initial setpoint switching command and generate verification results.

[0083] Specifically, three core verifications are conducted on the initial command: parameter consistency verification, format standardization verification, and object matching verification. Among them, parameter consistency verification checks the consistency between the setting parameters in the initial setting switching command and the final relay protection setting area of ​​P1, such as whether the instantaneous trip setting of 22kA is consistent with the verification result. Format standardization verification checks whether the format of the initial setting switching command conforms to the "Power Grid Dispatch Command Specification (Q / GDW1234-202X)", including the initial setting switching command encoding format such as PD-setting switching-P1-#001, and the field order such as operation object → setting area number → customized parameter → time window. Object matching verification compares the matching of the operation object P1-110kV-L1 of the initial setting switching command with the currently operating equipment in the power grid, that is, confirming that the P1 device is in operation and has no maintenance plan.

[0084] If the overcurrent action time limit in the initial setting switching command is mistakenly written as 0.6s, which does not match the final relay protection setting range of 0.5s, then the trigger parameters are inconsistent; if the initial setting switching command encoding format is missing the setting switching identifier, then the trigger format is incorrect; if the operation object is mistakenly written as device P2, then the trigger object does not match, and a verification result is generated.

[0085] D3. If the verification result is passed, the initial setting value switching instruction is submitted for manual approval. If the verification result is failed, the initial setting value switching instruction is modified according to the result category until the verification is passed and then submitted for manual approval. After the manual approval is passed, the final setting value switching instruction is obtained.

[0086] Specifically, the following actions will be taken based on the verification results: If the verification passes, the initial setting value switching instruction is submitted to the 110kV urban distribution network dispatch center for manual approval. If the verification fails, modifications are made based on the verification results. If the parameters are inconsistent, the process returns to step D1 to recalibrate the setting parameters in the initial setting value switching instruction, such as correcting the overcurrent action time limit to 0.5s. If the format is incorrect, the process returns to the initial setting value switching instruction editing stage to correct the encoding format and field order according to the dispatch specifications, such as adding a setting value switching identifier. If the object does not match, the process returns to the device information verification stage to confirm the P1 device number and update the operation object.

[0087] Once manually approved, the initial setting switch instruction will be designated as the final setting switch instruction.

[0088] In an optional implementation, step S400 may also include electronic signature verification, which involves introducing blockchain electronic signature technology in D2 to hash and encrypt the initial value switching instruction and store it on the blockchain to ensure that the transmission process of the initial value switching instruction is tamper-proof and to improve the credibility of the final value switching instruction.

[0089] In another optional implementation, step S400 can also include initial value switching instruction version traceability. The steps are as follows: add a version management module in D3 to record the traces of each modification, such as V1.0 parameter inconsistency correction, V2.0 format error correction, and V3.0 approval, to facilitate operation and maintenance auditing and fault traceability.

[0090] In this embodiment of the application, step S500, which involves evaluating the communication status of the field device and its ability to execute the final setpoint switching command, and generating a comprehensive evaluation report, includes steps E1 to E3: E1. After issuing the final setting switching command, monitor the field devices in real time and generate communication status assessment results.

[0091] Specifically, a two-way communication monitoring mechanism for the main station terminal is adopted to monitor the communication status of the P1 device by three core indicators: communication latency, packet loss rate, and signal strength. The monitoring results are then used to obtain a communication status assessment result. The communication latency is the round-trip latency between the device and the master station collected every 5 seconds, with a target threshold of ≤200ms; the packet loss rate is the proportion of communication data packets lost within 1 minute, with a target threshold of ≤1%; the signal strength is the real-time acquisition of signal power from the 4G / fiber optic module of the P1 device, with a target threshold of ≥-70dBm; if the average communication latency of the P1 device is 150ms, the packet loss rate is 0.5%, and the 4G signal strength is -65dBm, and all three indicators meet the threshold requirements, then the communication status assessment result is normal.

[0092] E2. Simultaneously monitor the execution progress of the field device in response to the final setpoint switching command, and generate an execution capability assessment result.

[0093] Specifically, the execution nodes of the P1 device for the final setting switch command are recorded through the command execution log built into the field device and the progress tracking module of the main station, and the execution capability assessment results are generated. For example, the device will respond that it has been received within 30 seconds after the final setting switch command is issued; the matching verification between the setting parameters and the device hardware will be completed within 2 minutes, such as the instantaneous trip setting of 22kA matching the hardware threshold of the P1 device; the final relay protection setting area will be switched within 5 minutes, and the device panel will display that setting area #001 has been activated; the protection function self-test will be completed within 1 minute after the switch, and the self-test will be reported as normal.

[0094] E3. Based on the communication status assessment results and execution capability assessment results, generate a comprehensive assessment report.

[0095] Specifically, the communication status assessment results of E1 and the execution capability assessment results of E2 are integrated to generate a comprehensive assessment report, which includes, but is not limited to, the following: assessment conclusions, data support, and operation and maintenance recommendations. For example, the P1 device communication is stable, the final setting switching command is executed efficiently, and the final relay protection setting area switching task is completed as expected.

[0096] In an optional implementation, AI predictive analysis can also be introduced in step S500. The steps are as follows: add a communication status prediction module to E1, and predict the communication stability for the next 24 hours based on historical communication latency and packet loss rate data through an LSTM model. If the predicted packet loss rate is greater than 1%, an early warning will be triggered.

[0097] In another optional implementation, step S500 can also include a multi-dimensional scoring mechanism, which involves introducing quantitative scoring in E3, such as 40 points for the communication status assessment result and 60 points for the execution capability assessment result, resulting in a comprehensive score of 95 points for device P1, which intuitively reflects the gradient of the comprehensive evaluation report.

[0098] In summary, this invention uses a 110kV urban distribution network as a scenario. First, it preprocesses initial grid data to obtain 28 characteristic grid data items. Then, it identifies the grid operation mode and filters candidate relay protection setting areas. After verification and risk assessment, the setting area under normal power supply conditions of device P1 is determined as the final relay protection setting area. After generating and approving the final setting switching command, the device communication status assessment results and execution capability assessment results are evaluated, and a comprehensive assessment report is generated. The entire process achieves adaptation between the relay protection setting area and the grid operating conditions, improving switching safety and operational reliability.

[0099] Example 3 illustrates a schematic scheme for an adaptive switching method for relay protection setting areas. It should be noted that the technical solution of this adaptive switching system for relay protection setting areas is based on the same concept as the aforementioned adaptive switching method for relay protection setting areas. Details not described in detail in this embodiment can be found in the description of the aforementioned adaptive switching method for relay protection setting areas.

[0100] This embodiment also provides a relay protection setting zone adaptive switching system, including: The data acquisition and preprocessing module is used to acquire initial power grid data and preprocess the initial power grid data to obtain characteristic power grid data. The operation mode identification module is used to identify the power grid operation mode by matching the characteristic power grid data with the pre-stored standard operation mode template; The setting range filtering module is used to filter out candidate relay protection setting ranges based on the identified power grid operation mode. The verification and pre-verification module is used to verify and pre-verify the candidate relay protection setting range to obtain the final relay protection setting range. The instruction generation and approval module is used to generate a corresponding initial setting switching instruction based on the final relay protection setting range, and to obtain the final setting switching instruction by verifying the initial setting switching instruction and manually approving it. The evaluation module is used to evaluate the communication status and execution capability of the field device after the final setting switching command is issued, and generate a comprehensive evaluation report.

[0101] This embodiment also provides an electronic device suitable for adaptive switching of relay protection setting zones, comprising: a memory and a processor; the memory is used to store computer-executable instructions, and the processor is used to execute the computer-executable instructions to implement the adaptive switching method for relay protection setting zones proposed in the above embodiment.

[0102] This embodiment also provides a storage medium storing a computer program that, when executed by a processor, implements the adaptive switching method for relay protection setting zones as proposed in the above embodiments.

[0103] The storage medium proposed in this embodiment and the method for adaptive switching of relay protection setting areas proposed in the above embodiments belong to the same inventive concept. Technical details not described in detail in this embodiment can be found in the above embodiments, and this embodiment has the same beneficial effects as the above embodiments.

[0104] Based on the above description of the implementation methods, those skilled in the art can clearly understand that the present invention can be implemented using software and necessary general-purpose hardware, and of course, it can also be implemented using hardware. Based on this understanding, the technical solution of the present invention, or the part that contributes to the prior art, can be embodied in the form of a software product. This computer software product can be stored in a computer-readable storage medium, such as a computer floppy disk, read-only memory (ROM), random access memory (RAM), flash memory, hard disk, or optical disk, etc., including several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute the methods of the various embodiments of the present invention.

[0105] It should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and not to limit it. Although the present invention has been described in detail with reference to preferred embodiments, those skilled in the art should understand that modifications or equivalent substitutions can be made to the technical solutions of the present invention without departing from the spirit and scope of the technical solutions of the present invention, and all such modifications or substitutions should be covered within the scope of the claims of the present invention.

Claims

1. A method for adaptive switching of relay protection setting zones, characterized in that, include: Initial power grid data is collected and preprocessed to obtain characteristic power grid data; The power grid operation mode is identified by matching the characteristic power grid data with the pre-stored standard operation mode template, and candidate relay protection setting areas are selected based on the identified power grid operation mode. The final relay protection setting range is obtained by verifying and pre-verifying the candidate relay protection setting range. The corresponding initial setting switching instruction is generated according to the final relay protection setting area, and the final setting switching instruction is obtained by verifying the initial setting switching instruction and manually approving it. After issuing the final setpoint switching command, the communication status of the field device and its ability to execute the final setpoint switching command are evaluated, and a comprehensive evaluation report is generated.

2. The adaptive switching method for relay protection setting zones as described in claim 1, characterized in that, The steps to obtain characteristic power grid data include: Initial power grid data is collected, and the initial power grid data is processed by data completion and time alignment to obtain time-aligned data; The time-aligned data is classified according to the physical variable type to obtain classified data; Data fusion is performed on the classified data belonging to the same physical variable to generate corresponding single physical variable data; Anomaly detection and cleaning are performed on the single physical variable data to obtain characteristic power grid data.

3. The adaptive switching method for relay protection setting zones as described in claim 2, characterized in that, The steps to identify the power grid operating mode include: Extract the power grid operation features from the characteristic power grid data, and normalize the power grid operation features to obtain normalized operation features; Pre-store standard operation mode templates, and calculate the distance result by comparing the normalized operation features with each of the standard operation mode templates; Based on the distance results, the power grid operation mode is identified through pattern matching and classification.

4. The adaptive switching method for relay protection setting zones as described in claim 3, characterized in that, The steps for selecting candidate relay protection setting ranges include: Based on the power grid operation mode, extract the corresponding normalized operation characteristics and the relay protection setting range adapted to the corresponding standard operation mode template, and calculate the initial matching degree between the normalized operation characteristics and the relay protection setting range; Set a matching threshold and use the relay protection setting area where the initial matching degree exceeds the matching threshold as the preliminary candidate setting area; Collect historical scenario data corresponding to the current power grid operation mode, extract the actual application effect data of the preliminary candidate setting area in each historical scenario, and calculate the historical effect score; combine the historical effect score to perform a weighted correction on the initial matching degree of the preliminary candidate setting area to obtain the corrected matching degree; Constraint conflict verification is performed on the preliminary candidate value areas to obtain feasibility verification results, and a comprehensive score is calculated by combining the corrected matching degree and historical effect score to obtain the candidate value areas to be ranked. The candidate setting areas to be ranked are sorted from high to low according to the comprehensive score, and the top five candidate setting areas are selected to form the candidate relay protection setting areas.

5. The adaptive switching method for relay protection setting zones as described in claim 4, characterized in that, The steps to obtain the final relay protection setting range include: A verification benchmark model is constructed, and the candidate relay protection setting area is verified according to the verification benchmark model to generate verification results; Based on the verification results, the candidate relay protection setting areas are pre-verified, a pre-verification report is generated, and the comprehensive risk value of each candidate relay protection setting area is calculated in conjunction with the verification results. A preset risk threshold is used to eliminate candidate relay protection setting areas whose comprehensive risk value exceeds the risk threshold, thereby obtaining candidate relay protection setting areas. The candidate relay protection setting areas are sorted from low to high according to their comprehensive risk values, and the candidate relay protection setting area with the highest ranking is selected as the final relay protection setting area.

6. The adaptive switching method for relay protection setting zones as described in claim 5, characterized in that, The steps to obtain the final setpoint switching instruction include: Generate the corresponding initial setting switching command based on the final relay protection setting area; The initial setpoint switching command is verified, and a verification result is generated; If the verification result is successful, the initial setting value switching instruction is submitted for manual approval. If the verification result is unsuccessful, the initial setting value switching instruction is modified according to the result category until the verification is successful and then submitted for manual approval. After the manual approval is successful, the final setting value switching instruction is obtained.

7. The adaptive switching method for relay protection setting zones as described in claim 6, characterized in that, The steps for evaluating the communication status of the field device and its ability to execute the final setpoint switching command, and generating a comprehensive evaluation report, include: After issuing the final setting switching command, the field devices are monitored in real time, and a communication status assessment result is generated; The execution progress of the field device in response to the final setpoint switching command is monitored synchronously, and an execution capability assessment result is generated. A comprehensive evaluation report is generated by combining the communication status evaluation results and the execution capability evaluation results.

8. A relay protection setting zone adaptive switching system, using the method described in any one of claims 1-7, characterized in that, include: The data acquisition and preprocessing module is used to acquire initial power grid data and preprocess the initial power grid data to obtain characteristic power grid data. The operation mode identification module is used to identify the power grid operation mode by matching the characteristic power grid data with the pre-stored standard operation mode template; The setting range filtering module is used to filter out candidate relay protection setting ranges based on the identified power grid operation mode. The verification and pre-verification module is used to verify and pre-verify the candidate relay protection setting range to obtain the final relay protection setting range. The instruction generation and approval module is used to generate a corresponding initial setting switching instruction based on the final relay protection setting range, and to obtain the final setting switching instruction by verifying the initial setting switching instruction and manually approving it. The evaluation module is used to evaluate the communication status and execution capability of the field device after the final setting switching command is issued, and generate a comprehensive evaluation report.

9. An electronic device, comprising: Memory and processor; The memory is used to store computer-executable instructions, and the processor is used to execute the computer-executable instructions. When the computer-executable instructions are executed by the processor, they implement the steps of the adaptive switching method for relay protection setting zones as described in any one of claims 1 to 7.

10. A computer-readable storage medium storing computer-executable instructions that, when executed by a processor, implement the steps of the adaptive switching method for relay protection setting zones as described in any one of claims 1 to 7.

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