Topology evolution aware power grid section control limit dynamic adjustment method and system

Abstract

This invention provides a method and system for dynamic adjustment of power grid cross-section control limits based on topology evolution awareness, relating to the field of data processing technology. The method includes: acquiring synchronous phasor state data of power grid feeders; preprocessing the synchronous phasor state data to obtain a time-series data stream, which includes equipment status signals and electrical measurement data; identifying state change events of circuit breakers and disconnectors based on the equipment status signals and a preset initial topology connection relationship, and updating the initial topology connection relationship according to the state change events to obtain a real-time topology state; calculating and generating a reliable cross-section based on the real-time topology state and electrical measurement data, and verifying the reliable cross-section to obtain a reliable topology state. This invention can effectively ensure the safe and stable operation of the power grid and improve the adaptability and control accuracy of the power grid topology.

Description

Technical Field

[0001] This invention relates to the field of data processing technology, and in particular to a method and system for dynamic adjustment of power grid cross-section control limits based on topology evolution sensing. Background Technology

[0002] In the actual operation of the power grid, dispatchers typically monitor and control the operating status of transmission sections in real time based on the pre-calculated control limit values ​​of the transmission sections, which are fixed in the dispatch automation system, to ensure the safe and stable operation of the power grid. Currently, most of these control limit values ​​are calculated based on offline simulation data under typical power grid operating conditions, which can well meet basic monitoring needs when the power grid is in the preset typical operating state. In the daily operation of the power grid, various planned maintenance work for equipment is inevitable. Planned maintenance of 10 kV feeders is relatively common. For example, if a 10 kV feeder needs to be suspended due to municipal road construction or upgrading of old lines, in order to ensure the normal power supply to users within the feeder's power supply range, staff will use the interconnection switch to smoothly transfer the 311 distribution transformer loads supplied by the suspended feeder to the adjacent 10 kV feeder for power supply, achieving uninterrupted power supply during maintenance and ensuring the continuity of power supply.

[0003] Such load transfer operations directly lead to dynamic adjustments in the topology of the local power grid. However, existing dispatch automation systems often struggle to track these dynamic changes in the local topology in real time during the calculation of cross-section control limits, and cannot update the calculation basis of cross-section control limits in a timely manner according to the topology adjustment. In this case, if dispatchers continue to monitor the transmission cross-sections in the area using the fixed control limits set before the topology change, the calculation basis will deviate from the actual physical form and load distribution of the current power grid, resulting in insufficient accuracy in assessing the cross-section transmission capacity and potentially failing to fully guarantee the safe and stable operation of the power grid after dynamic topology adjustments. Summary of the Invention

[0004] The technical problem to be solved by the present invention is to provide a method and system for dynamic adjustment of grid cross-section control limits based on topology evolution perception, which can effectively ensure the safe and stable operation of the power grid and improve the topology adaptability and control accuracy of the power grid.

[0005] To solve the above-mentioned technical problems, the technical solution of the present invention is as follows: Firstly, a topology-evolution-aware dynamic adjustment method for grid section control limits, the method comprising: Step 1: Collect the synchronous phasor status data of the power grid feeder, preprocess the synchronous phasor status data of the power grid feeder to obtain the time-series data stream, which includes equipment status signals and electrical measurement data; Step 2: Based on the equipment status signal and the preset initial topology connection relationship, identify the status change events of the circuit breaker and disconnector, and update the initial topology connection relationship according to the status change events to obtain the real-time topology status. Step 3: Calculate and generate a reliable cross section based on the real-time topology status and electrical measurement data, and verify the reliable cross section to obtain the reliable topology status; Step 4: Based on the reliable topology state, select the core bus of the power collection area at the sending end, the hub bus of the load center at the receiving end, and the key interconnection bus of the regional power grid as three topology sensing base points in the power grid. The topology sensing base points are connected to form a topology sensitive domain. The topology sensitive domain is divided to obtain multiple electrical equivalent blocks. The response weight is calculated based on the bus voltage phase angle and line active power in each electrical equivalent block. Step 5: Calculate and analyze the trusted topology state and response weights to obtain the key transmission sections; Step 6: Based on the key transmission sections, combined with the reliable topology state, response weights, and electrical measurement data, calculate the dynamic control limit values. Step 7: Generate and issue control adjustment commands based on the dynamic control limit values ​​to ensure the safe and stable operation of the power grid.

[0006] The second aspect is a topology-evolution-aware dynamic adjustment system for grid cross-section control limits, including: The acquisition module is used to acquire synchronous phasor status data of power grid feeders, preprocess the synchronous phasor status data of power grid feeders to obtain a time-series data stream, which includes equipment status signals and electrical measurement data. The update module is used to identify the status change events of circuit breakers and disconnectors based on the equipment status signals and the preset initial topology connection relationship, and update the initial topology connection relationship according to the status change events to obtain the real-time topology status. The verification module is used to calculate and generate a reliable cross section based on the real-time topology status and electrical measurement data, and to verify the reliable cross section to obtain the reliable topology status. The calculation module is used to select the core bus of the power collection area at the sending end, the hub bus of the load center at the receiving end, and the key interconnection bus of the regional power grid as three topology sensing base points in the power grid according to the reliable topology state. The topology sensing base points are connected to form a topology sensitive domain. The topology sensitive domain is divided into multiple electrical equivalent blocks. The response weight is calculated based on the bus voltage phase angle and line active power in each electrical equivalent block. The analysis module is used to calculate and analyze the reliable topology state and response weights to obtain the key transmission sections; The processing module is used to calculate the dynamic control limit value based on the key transmission section, combined with the reliable topology state, response weights and electrical measurement data; The output module is used to generate and issue control adjustment commands based on dynamic control limit values ​​to ensure the safe and stable operation of the power grid.

[0007] Thirdly, a computing device includes: One or more processors; A storage device for storing one or more programs that, when executed by one or more processors, cause the one or more processors to implement the method.

[0008] The above-described solution of the present invention has at least the following beneficial effects: This invention selects key buses at the sending end, receiving end, and regional interconnection as topology sensing base points, constructs a topology sensitive domain and divides it into electrical equivalent blocks, calculates response weights by combining bus voltage phase angle and line active power, and identifies key transmission sections through comprehensive weight screening and load rate verification. This can accurately locate the core sections affecting power supply security after grid topology adjustments, eliminate interference from non-critical sections, and provide targeted focus for control limit calculations. Based on reliable topology state, response weights, and real-time electrical measurement data, the static limit values ​​of key transmission sections are weighted and corrected to generate dynamic control limit values ​​adapted to the current topology state. This effectively eliminates the deviation between the calculation basis after topology adjustments and the actual operating state of the grid, and improves the accuracy of section transmission capacity assessment. Attached Figure Description

[0009] Figure 1 This is a schematic flowchart of a topology evolution-aware dynamic adjustment method for grid section control limits provided in an embodiment of the present invention.

[0010] Figure 2 This is a schematic diagram of a topology evolution-aware dynamic adjustment system for grid cross-section control limits provided in an embodiment of the present invention. Detailed Implementation

[0011] Exemplary embodiments of the present disclosure will now be described in more detail with reference to the accompanying drawings. While exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure may be implemented in various forms and should not be limited to the embodiments set forth herein. Rather, embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the disclosure to those skilled in the art.

[0012] like Figure 1 As shown, embodiments of the present invention propose a method for dynamic adjustment of grid section control limits based on topology evolution awareness. The method includes the following steps: Step 1: Collect the synchronous phasor status data of the power grid feeder, preprocess the synchronous phasor status data of the power grid feeder to obtain the time-series data stream, which includes equipment status signals and electrical measurement data; Step 2: Based on the equipment status signal and the preset initial topology connection relationship, identify the status change events of the circuit breaker and disconnector, and update the initial topology connection relationship according to the status change events to obtain the real-time topology status. Step 3: Calculate and generate a reliable cross section based on the real-time topology status and electrical measurement data, and verify the reliable cross section to obtain the reliable topology status; Step 4: Based on the reliable topology state, select the core bus of the power collection area at the sending end, the hub bus of the load center at the receiving end, and the key interconnection bus of the regional power grid as three topology sensing base points in the power grid. The topology sensing base points are connected to form a topology sensitive domain. The topology sensitive domain is divided to obtain multiple electrical equivalent blocks. The response weight is calculated based on the bus voltage phase angle and line active power in each electrical equivalent block. Step 5: Calculate and analyze the trusted topology state and response weights to obtain the key transmission sections; Step 6: Based on the key transmission sections, combined with the reliable topology state, response weights, and electrical measurement data, calculate the dynamic control limit values. Step 7: Generate and issue control adjustment commands based on the dynamic control limit values ​​to ensure the safe and stable operation of the power grid.

[0013] In this embodiment of the invention, the present invention selects the sending end, receiving end, and key interconnection buses of the region as the topology sensing base points, constructs a topology sensitive domain and divides it into electrical equivalent blocks, calculates the response weights by combining the bus voltage phase angle and line active power, and identifies key transmission sections through comprehensive weight screening and load rate verification. This can accurately locate the core sections that affect power supply security after the grid topology adjustment, eliminate interference from non-critical sections, and provide targeted focus for control limit calculation. Based on the reliable topology state, response weights, and real-time electrical measurement data, the static limit values ​​of key transmission sections are weighted and corrected to generate dynamic control limit values ​​that adapt to the current topology state. This effectively eliminates the deviation between the calculation basis after topology adjustment and the actual operating state of the grid, and improves the evaluation accuracy of the transmission capacity of the sections.

[0014] In a preferred embodiment of the present invention, step 1 involves acquiring grid feeder synchronization phasor state data, preprocessing the grid feeder synchronization phasor state data to obtain a time-series data stream, which includes equipment status signals and electrical measurement data, and may include: Step 101: Collect grid feeder synchronous phasor status data, including grid status signals, synchronization phasor data, and feeder data. The grid status signals include the status information of circuit breakers and disconnectors; the synchronization phasor data includes bus voltage amplitude, bus voltage phase angle, line active power, and line reactive power; and the feeder data includes feeder active power and feeder reactive power. Specifically, this involves comprehensively collecting grid feeder synchronous phasor status data using synchronization phasor measurement devices, feeder monitoring terminals, and equipment status acquisition devices deployed at each feeder node. The collection scope covers various key data related to feeders during grid operation. The acquisition frequency is set to 25 Hz to 50 Hz, and the acquisition period is 1 second to 5 seconds. Specifically, it includes three core data types: grid status signals, synchronization phasor data, and feeder data. The grid status signals mainly collect real-time operating status information of all circuit breakers and disconnectors in the grid, using binary signals to represent equipment status, with values ​​of 0 or 1, where 0 represents the open state and 1 represents the closed state, clearly indicating the current status of each circuit breaker and disconnector. Whether the circuit breaker is closed or open directly reflects the connection status of the power grid equipment and is the basis for subsequent identification of topology changes. Synchronous phasor data focuses on collecting the voltage amplitude and phase angle of each bus in the power grid, as well as the active and reactive power of each transmission line. The bus voltage amplitude ranges from 0.9 times the rated voltage to 1.1 times the rated voltage, specifically 10 kV, 35 kV, 110 kV, and 220 kV. The bus voltage phase angle ranges from -180 degrees to 180 degrees. The active power of the line ranges from 0 MW to the rated active power of the line. The rated active power of the line is determined according to the line model and ranges from 10 MW to 500 MW. The reactive power of the line ranges from -100 Mvar to 100 Mvar. These data can accurately reflect the real-time electrical operation status of the power grid. The feeder data mainly collects the active power and reactive power of each 10 kV feeder. The active power of the 10 kV feeder ranges from 0 MW to 10 MW, and the reactive power of the 10 kV feeder ranges from -5 Mvar to 5 Mvar.

[0015] Step 102: Time synchronization processing is performed on the power grid status signal, synchronization phasor data, and feeder data to obtain time-aligned synchronization data; the time-aligned synchronization data is filtered to obtain clean data; the clean data is normalized to obtain normalized data; the portion of the normalized data corresponding to the power grid status signal is reconstructed to obtain the equipment status signal; the portion of the normalized data corresponding to the synchronization phasor data and feeder data is reconstructed to obtain electrical measurement data; the electrical measurement data includes bus voltage amplitude, bus voltage phase angle, line active power, line reactive power, feeder active power, and feeder reactive power, specifically including: time synchronization processing of the power grid status signal, synchronization phasor data, and feeder data, with the time synchronization accuracy set to 1 millisecond to 10 milliseconds. Since the three types of data come from different acquisition devices, there may be slight differences in the acquisition time. To ensure subsequent... To ensure the accuracy of data processing and analysis, all data must be aligned to the same time base. This is achieved using timestamp calibration, with GPS standard time as the benchmark. The acquisition time of each data point is adjusted to a unified standard time, using the format YYYY-MM-DDHH:MM:SS.fff, thus obtaining time-aligned synchronized data. This time-aligned synchronized data is then filtered using a moving average filtering method, with a filtering window size set to 3 to 5 acquisition cycles. This primarily targets and removes potential random interference signals, acquisition errors, and abnormal fluctuations in the data. Specifically, valid data conforming to the normal operating patterns of the power grid is retained, while abnormal jumps caused by acquisition equipment failure or external interference are removed. The criterion for judging abnormal jumps is that the difference between two adjacent acquisition cycles exceeds the rated value for that type of data by 10%, ensuring data cleanliness and yielding clean data.

[0016] Cleaning data is normalized using a linear normalization method, adjusting data of different types and magnitudes to the same numerical range. The specific calculation process involves subtracting the minimum value of each data point in each data category from the minimum value of that category, and then dividing by the difference between the maximum and minimum values ​​of that category. This ensures all data points fall within the range of 0 to 1, resulting in normalized data. The specific calculation formula is as follows: ,in Here are the normalized data, and x is the original data. The minimum value of this type of data. The maximum value of this type of data is determined by the historical data collected in statistical step 101 (collection time not less than 24 hours). The normalized data is reorganized. According to the data type, the part of the normalized data corresponding to the power grid status signal is extracted and integrated separately to form the equipment status signal. This signal completely retains the normalized status information of all circuit breakers and disconnectors. The parts of the normalized data corresponding to the synchronous phasor data and feeder data are extracted and integrated together to form electrical measurement data. This electrical measurement data completely includes the normalized data of bus voltage amplitude, bus voltage phase angle, line active power, line reactive power, feeder active power, and feeder reactive power.

[0017] This embodiment clarifies key details such as time synchronization accuracy, filtering window size, and normalization calculation process through preprocessing operations such as time synchronization, filtering, normalization, and data reconstruction. It eliminates data interference and magnitude differences, obtains a standardized time-series data stream, ensures the accuracy and consistency of data use in subsequent steps, and improves the reliability of data processing.

[0018] In a preferred embodiment of the present invention, step 2, which involves identifying state change events of circuit breakers and disconnectors based on device status signals and a preset initial topology connection relationship, and updating the initial topology connection relationship according to the state change events to obtain the real-time topology status, may include: Step 201: Compare the status information of circuit breakers and disconnectors in the equipment status signals with the corresponding equipment status in the preset initial topology connection relationship, detect circuit breakers and disconnectors that have undergone status changes, and identify status change events. Specifically, this includes: first, obtaining the preset initial topology connection relationship, which is pre-constructed based on the normal operating conditions of the power grid. The construction process combines the actual physical wiring diagram of the power grid, equipment ledger information, and historical operating data to clarify the initial connection relationship between each circuit breaker, disconnector, busbar, and line, as well as the initial operating status of each device; the initial status is adopted... The initial topology is represented by binary signals, with values ​​of 0 or 1. 0 indicates the open state and 1 indicates the closed state. The initial topology connection relationship is stored in the form of an adjacency matrix. The rows and columns of the adjacency matrix correspond to the unique numbers of all devices in the power grid. The device numbers are numbered sequentially in the order of bus, line, circuit breaker, and disconnector. The adjacency matrix element takes the value of 0 or 1. 0 indicates that there is no direct connection between the devices in the corresponding row and column, and 1 indicates that there is a direct connection between the devices in the corresponding row and column. The dimension of the adjacency matrix is ​​consistent with the total number of devices in the power grid. For example, when the power grid contains 100 devices of various types, the adjacency matrix is ​​a 100×100 matrix.

[0019] The initial topology connection also associates and stores the basic parameters of each device, including circuit breaker rated current, disconnector model, bus rated voltage, line impedance, etc., providing a reference for subsequent state comparison and topology updates. Real-time status information of all circuit breakers and disconnectors is extracted from the device status signals. This real-time status information is still a binary signal of 0 or 1. This real-time status information is compared one by one with the initial status of the corresponding circuit breaker and disconnector in the preset initial topology connection. A difference judgment method is used to complete the comparison. Specifically, for each circuit breaker and disconnector, its initial state value and real-time state value are extracted first, then the difference between the real-time state value and the initial state value is calculated. If the calculated difference is... A difference of 1 indicates that the device has changed from an open state to a closed state. A difference of -1 indicates that the device has changed from a closed state to an open state. In both cases, the device's state is considered to have changed. A difference of 0 indicates that the device's real-time state is consistent with its initial state, and the device's state is considered not to have changed. The comparison operation is performed on all circuit breakers and disconnectors one by one. Through comparison, all circuit breakers and disconnectors whose states have changed are detected. For example, a circuit breaker that was originally in the closed state (value 1) changes to the open state (value 0), and a disconnector that was originally in the open state (value 0) changes to the closed state (value 1). The events corresponding to these devices whose states have changed are called state change events.

[0020] Step 202: Based on the state change event, modify the corresponding device status in the preset initial topology connection relationship to obtain the updated topology connection relationship; perform connectivity analysis and verification on the updated topology connection relationship to obtain the real-time topology status. Specifically, this includes: based on the state change event identified in step 201, making targeted modifications to the preset initial topology connection relationship. This initial topology connection relationship has been pre-associated with the device's basic parameters and physical wiring information. When modifying, it is necessary to confirm the device association relationship with the device ledger to avoid modification deviations; for each circuit breaker or disconnector that has experienced a state change, first modify its corresponding status in the initial topology connection relationship, changing the initial status value from 0 to 1 or 1 to 0, and simultaneously adjust the connection relationship corresponding to the device. The method involves modifying the values ​​of elements at corresponding positions in the adjacency matrix. For example, if a circuit breaker changes from closed to open, the row corresponding to the circuit breaker number and the column corresponding to the line and bus number in the adjacency matrix of the topology connection relationship need to be found, and the value of the element at the corresponding position needs to be changed from 1 to 0, thereby deleting the line connection corresponding to the circuit breaker. If a disconnector changes from open to closed, the row corresponding to the disconnector number and the column corresponding to the device number need to be found in the adjacency matrix of the topology connection relationship, and the value of the element at the corresponding position needs to be changed from 0 to 1, thereby adding the device connection corresponding to the disconnector. Through such modifications, the updated topology connection relationship is obtained. The updated topology connection relationship is still stored in the form of an adjacency matrix, and the status information of the associated devices is updated synchronously.

[0021] The updated topology connections are subjected to connectivity analysis and verification. The connectivity analysis employs a depth-first search (DFS) method. Specifically, any bus node in the main power grid is selected as the starting search node and marked as visited. Then, starting from this node, all elements with a value of 1 in the corresponding row of the adjacency matrix are searched to identify all directly connected neighboring nodes. Each unmarked neighboring node is visited one by one and marked as visited. This process is repeated, starting with each neighboring node as a new starting node, until no new unvisited nodes are found. After the search is complete, all visited nodes are counted and compared with the total number of all equipment nodes in the power grid. If the number of visited nodes matches the total number of equipment nodes, the power grid topology is connected, and there are no isolated devices or regions. If the number of visited nodes is less than the total number of equipment nodes, isolated regions exist. Isolated region determination... The standard is that all nodes in the area are unvisited and cannot be connected to the initial main grid bus node via any path, ensuring that the topology connection relationship can truly reflect the actual physical connection of the power grid. The verification process mainly involves checking whether the updated topology connection relationship completely matches the real-time status in the device status signals. The status and connection relationship of each device are checked one by one to check for any omissions or errors in the modifications. At the same time, combined with the actual operation experience of the power grid and the device parameters associated with the initial topology connection relationship, it is determined whether the updated topology connection relationship conforms to the power grid operation specifications. For example, whether the connection between the relevant feeder and the adjacent feeder is correct after load transfer, and whether there are any connection logic errors. The criteria for judging connection logic errors are inconsistent device status at both ends of the same line and the bus and feeder connection relationship not conforming to the actual physical wiring. Through connectivity analysis and verification, erroneous topology connection relationships are eliminated, and the real-time topology status is finally obtained.

[0022] This embodiment clarifies the state representation method, comparison method, and topology update rules by accurately identifying the state change events of circuit breakers and disconnectors. At the same time, it updates and verifies the topology connection relationship in a timely manner, clarifies the connectivity analysis method and verification standard, realizes real-time perception of the power grid topology status, and solves the problem of not being able to track local topology dynamic changes in real time.

[0023] In a preferred embodiment of the present invention, step 3, calculating and generating a reliable cross-section based on the real-time topology status and electrical measurement data, and verifying the reliable cross-section to obtain the reliable topology status, may include: Step 301 involves obtaining device connection relationships from the real-time topology state, and extracting bus voltage amplitude, bus voltage phase angle, line active power, line reactive power, feeder active power, and feeder reactive power from electrical measurement data. The device connection relationships are then assembled with the electrical measurement data to obtain an initial profile containing device connection status, electrical measurement values, and measurement directions. Specifically, this includes: fully extracting the connection relationships of all devices from the real-time topology state, including the connections between each bus and line, line and circuit breaker, and circuit breaker and disconnector. The extraction method involves reading the adjacency matrix of the real-time topology state, parsing the device connection relationships corresponding to the positions where the element with a value of 1 in the adjacency matrix, and clarifying the current connections of all devices in the power grid. The system extracts all key electrical measurement parameters from electrical measurement data, including bus voltage amplitude, bus voltage phase angle, line active power, line reactive power, feeder active power, and feeder reactive power. The extraction process involves filtering data of corresponding types based on data tags to ensure the completeness and accuracy of the extracted electrical measurement data, reflecting the real-time electrical operating status of the power grid. The extracted data is accurate to three decimal places, with voltage amplitude in kilovolts, voltage phase angle in degrees, and power in megawatts and megavars. Next, the extracted equipment connection relationships are assembled with the electrical measurement data, matching the electrical measurement values ​​corresponding to each equipment connection. The matching method involves matching the equipment connection relationship with the corresponding quantity based on the equipment number. The measurement data is correlated, and the measurement direction of each electrical measurement value is clearly defined. The measurement direction is represented by positive and negative values. For line active power, a positive value indicates that power flows from the bus to the line, and a negative value indicates that power flows from the line to the bus. For feeder power, a positive value indicates that power is injected from the grid into the feeder, and a negative value indicates that power is fed back from the feeder to the grid. In this process, a polygon nested hierarchical analysis algorithm is incorporated to perform hierarchical filtering and priority sorting of equipment connection relationships and electrical measurement data, providing accurate support for the initial cross-section generation. The specific process of the algorithm is as follows: a polygon nested hierarchical structure is constructed, with the main grid bus as the core layer, and the innermost polygon is constructed. The vertices of the polygon are the key equipment nodes corresponding to the core bus, and the vertex coordinates are determined by the equipment number and the corresponding electrical measurement value. The coordinates are determined after normalization processing (bus voltage amplitude, line active power). The normalization processing adopts the linear normalization method in step 102 to ensure that the coordinate values ​​are in the range of 0 to 1. Based on the core layer polygon, a second layer of polygons is nested outward, with the vertices being the lines and circuit breaker nodes directly connected to the core bus. The vertices of the third layer of polygons are the disconnecting switches and feeder nodes, forming a three-layer polygon nesting structure. The number of nesting layers is preset to 3. The number of edges of each layer of polygons is consistent with the number of equipment nodes in the corresponding layer. The edge weight is set as the connection reliability coefficient of the corresponding equipment, with a value range of 0.8 to 1.0. The connection reliability coefficient is determined based on the equipment's operating years and historical fault data. The longer the operating years and the more faults, the smaller the coefficient.

[0024] A hierarchical analysis is performed on each layer of polygons to calculate the centroid coordinates of each layer. The centroid coordinates are calculated by taking the average x-coordinate of all vertices in each layer as the centroid x-coordinate and the average y-coordinate of all vertices as the centroid y-coordinate. Then, the distance from each vertex to the centroid is calculated by taking the Euclidean distance between the vertex coordinates and the centroid coordinates. The preset distance threshold is 0.1 to 0.3. Vertices whose distance values ​​exceed this threshold are marked as low priority for their corresponding device nodes and measurement data. High priority nodes and data whose distance values ​​are within the threshold range are retained first. Through this hierarchical filtering and priority sorting, the accuracy and efficiency of the assembled initial cross-section data are ensured, ultimately forming an initial cross-section that includes device connection status, electrical measurement values, and measurement directions.

[0025] Step 302: Based on the equipment connection relationship, calculate the voltage phase angle difference using the bus voltage phase angle and compare it with the line active power to obtain the first comparison result; based on the equipment connection relationship, calculate the injected power using the line active power and line reactive power and compare it with the feeder active power and feeder reactive power to obtain the second comparison result; based on the two comparison results, identify abnormal measurement data exceeding the preset threshold, specifically including: based on the equipment connection relationship in the initial cross-section, combined with the layering result of the polygon nested hierarchical analysis algorithm, first determine the connection lines between each bus, clarify the bus number at both ends of each line, and prioritize the high-priority lines and bus nodes selected by the algorithm for subsequent calculations; then, using the bus voltage phase angle extracted from the initial cross-section, calculate the voltage phase angle difference between the two ends of each connection line, the calculation process being the voltage phase angle of the bus at one end of the line. Subtract the voltage phase angle of the other bus. The calculation formula is: The voltage phase angle difference corresponding to each line is obtained. The voltage phase angle difference ranges from -360 degrees to 360 degrees. If the calculated result exceeds this range, it is adjusted by adding or subtracting 360 degrees to bring the result within the range. The calculated voltage phase angle difference for each line is then used to calculate the voltage phase angle difference. The active power of the line in the electrical measurement data corresponding to this line The comparison is performed, and the hierarchical weights of the polygon nesting hierarchy analysis algorithm are combined to assign different comparison weights w to the lines at different levels, with the core layer lines having the highest comparison weights. The preset weight is 0.8 to 1.0, and the second-layer line comparison weight is... The preset weight is 0.6 to 0.8, and the third-layer line comparison weight is... The default value is 0.4 to 0.6. The weight value is inversely proportional to the average distance of the polygon layer from the centroid. The closer the distance, the greater the weight.

[0026] There is a fixed correlation between the active power of the line and the phase angle difference of the voltage at both ends of the bus. The correlation coefficient k is determined based on the line impedance, and its value ranges from 0.01 MW / kWh to 0.1 MW / kWh. The specific calculation method is based on the theoretical value of the line active power. Equals the correlation coefficient k multiplied by the voltage phase angle difference Then multiply by the comparison weight w of the corresponding level, the calculation formula is as follows: The calculated theoretical value of the line active power The measured active power of the line Compare the two and calculate their ratio. The preset reasonable ratio range is 0.8 to 1.2. When the ratio When the data exceeds the preset range, the relevant measurement data of the line is determined to be abnormal, thus obtaining the first comparison result. Based on the equipment connection relationship and the polygon nesting hierarchy analysis results, the feeder connection status of each bus is determined, the number and number of feeders connected to each bus are clarified, and the feeder data corresponding to high-priority buses are given priority. Using the active power and reactive power of each line, the injected power of the corresponding bus is calculated. The calculation process is to add the active power of all connected lines of the bus to obtain the active injected power of the bus. ,Right now The reactive power injected into the bus is obtained by adding up the reactive power of all lines connected to the bus. ,Right now ,in , These represent the active and reactive power of a single line, respectively. To determine the hierarchical weights of the corresponding lines, the calculation must distinguish between positive and negative power based on the measurement direction. Power flowing into the bus is taken as positive values, and power flowing out of the bus is taken as negative values.

[0027] The calculated active power injected into the bus Reactive power injection The sum of the active power of all feeders corresponding to that bus. The sum of reactive power of all feeders Compare the two and calculate the difference. The formula for calculating the active power difference is: The formula for calculating reactive power difference is: According to the power balance principle of the power grid, the power injected into the bus and the power of the feeder should maintain a reasonable balance. The preset difference threshold is the rated power of the bus. 5% of the rated power of the busbar The value ranges from 10 MW to 1000 MW. The threshold difference between different bus levels can be adjusted appropriately, with the core bus threshold set at 0.03. Up to 0.05 The threshold value for non-core layer busbars is set to 0.05. Up to 0.08 When the difference or When the corresponding preset threshold is exceeded, it is determined that the feeder power or line power measurement data corresponding to the bus is abnormal, thus obtaining the second comparison result; finally, combining the first comparison result and the second comparison result, and combining the priority sorting of the polygon nested hierarchical analysis algorithm, the abnormal data of high priority nodes are confirmed first, and all abnormal measurement data exceeding the preset threshold are comprehensively judged and identified.

[0028] Step 303: Correct and calculate the abnormal measurement data to obtain the updated cross-section; compare the device connection status in the updated cross-section with the real-time topology status. If they match, the updated cross-section is taken as a reliable cross-section, and the reliable topology status is obtained based on the confirmed topology status in the reliable cross-section. Specifically, this includes: for the identified abnormal measurement data, combining the hierarchical results and weight allocation of the polygon nested hierarchical analysis algorithm, performing correction and calculation. The correction process incorporates historical power grid operation data. The historical data is selected from normal measurement data under the same operating conditions within the past 3 months. The operating condition classification standard is the power grid load factor, and the load factor range is divided into four intervals: 0 to 0.3, 0.3 to 0.6, 0.6 to 0.9, and 0.9 to 1.0. Different levels of device nodes correspond to different historical data screening weights. The core layer node screening weight is preset to 0.9 to 1.0, the second layer node screening weight is preset to 0.7 to 0.9, and the third layer node... The screening weight is preset to 0.5 to 0.7, and the weight value is consistent with the hierarchical weight in the algorithm. Abnormal measurement data is adjusted by referring to normal measurement data of the same type of equipment under the same operating conditions. The adjustment method is to calculate the average value of normal measurement data under the same operating conditions and then multiply it by the corresponding level's screening weight to correct the abnormal measurement data to this calculated value. For abnormal data with large deviations, the deviation judgment standard is that the difference between the abnormal data and the average value under the same operating conditions exceeds 10% of the average value. The data is then recalculated based on the equipment connection relationship, electrical measurement logic, and the centroid distance data of the polygon nested hierarchical analysis algorithm. The recalculation process involves using the theoretical calculation method in step 302, combined with the normal measurement data of adjacent high-priority equipment, to infer the reasonable value of the abnormal data. Simultaneously, the distance from the node to the centroid of the corresponding level is referenced; the closer the distance, the greater the inference weight, ensuring that the corrected measurement data conforms to the actual operation of the power grid and avoiding cross-sectional distortion due to abnormal data.

[0029] By correcting and calculating the abnormal measurement data, an updated cross-section is obtained. This updated cross-section includes the corrected electrical measurement data and the corresponding equipment connection status. The equipment connection relationships in the updated cross-section are then comprehensively compared with the real-time topology status obtained in step 202. Using the hierarchical structure of the polygon nested hierarchical analysis algorithm, the connection status of each layer of equipment is checked one by one. The check method involves comparing the adjacency matrices of the two, checking whether the values ​​of the elements at corresponding positions are completely consistent, and simultaneously checking the centroid coordinates and vertex distribution of each layer of polygons. The preset centroid coordinate deviation threshold is 0.01 to 0.05. If the centroid coordinate deviation exceeds this threshold, the equipment connection relationships and measurement data need to be re-checked to confirm the connection status. If the connection relationships and equipment status are completely consistent and there is no deviation, it means that the updated section can truly and accurately reflect the current topology and electrical operation status of the power grid, and the updated section is determined as a reliable section. If the two are inconsistent, return to step 302 to re-identify abnormal measurement data and make corrections until the updated section is consistent with the real-time topology status. Based on the topology status confirmed in the reliable section, combined with the hierarchical results of the polygon nested hierarchical analysis algorithm, extract the equipment connection relationships and equipment status information, prioritize the extraction of high-priority node information, and extract the equipment connection data and status data of the reliable section by parsing the equipment connection data and status data, and synchronously update the parameters of each layer of the polygon nested hierarchical structure to obtain the reliable topology status.

[0030] This embodiment clarifies the anomaly judgment threshold, correction method and calculation process by generating an initial cross section, identifying and correcting abnormal measurement data, and finally obtaining a reliable cross section and reliable topological state, thus eliminating the interference of abnormal measurement data.

[0031] In a preferred embodiment of the present invention, step 4 involves selecting, based on the reliable topology state, the core busbar of the sending-end power collection area, the hub busbar of the receiving-end load center, and the key interconnection busbar of the regional power grid as three topology sensing base points in the power grid. These three base points are connected to form a topology sensitive domain. The topology sensitive domain is then divided to obtain multiple electrical equivalent blocks. Response weights are calculated based on the bus voltage phase angle and line active power within each electrical equivalent block, and may include: Step 401: Based on the device connection relationships and electrical measurement data contained in the trusted topology state, identify the sending-end power collection area, the receiving-end load center area, and the inter-regional interconnection channel from the power grid. Based on the power injection scale or electrical location importance of the buses in each area, select one core bus from the sending-end power collection area as the core bus of the sending-end power collection area, select one hub bus from the receiving-end load center area as the hub bus of the receiving-end load center, and select one key interconnection bus from the inter-regional interconnection channel as the key interconnection bus for regional power grid interconnection. These three selected buses are then designated as three... Topology sensing base points specifically include: identifying the sending-end power collection area, the receiving-end load center area, and the inter-regional interconnection channel from the power grid. The specific implementation process is as follows: traversing the power injection data and equipment connection relationships of all buses in the trusted topology state, calculating the total power output of each bus, determining the continuous area with the largest total power output as the sending-end power collection area, calculating the total feeder load of each bus, determining the continuous area with the largest total feeder load as the receiving-end load center area, and determining the line channels that connect different power supply zones and undertake inter-regional power exchange as inter-regional interconnection channels.

[0032] The process of identifying each region incorporates an axis-aligned bounding box (AABB) intersection detection algorithm. The calculation involves constructing an independent axis-aligned bounding box for each bus in the power grid. The coordinate axes of the bounding box are based on the geographical coordinates or electrical topology coordinates of the power grid, with the X-axis representing the horizontal coordinates and the Y-axis representing the vertical coordinates. The boundary range of the bounding box is determined based on the electrical influence radius of the equipment group to which the bus belongs. Specifically, the calculation method uses the bus's own coordinates... Centered on, with horizontal boundaries as The vertical boundary is R is the electrical influence radius, which is determined based on the rated voltage of the busbar. The higher the rated voltage, the larger the influence radius. It is usually taken from 0.5 to 2.0 electrical node spacings.

[0033] The intersection of different bus bounding boxes is detected using the Axis Aligned Bounding Box (AABB) intersection detection algorithm. Specifically, for any two bus bounding boxes A and B, the lateral left boundary of bounding box A is extracted. Horizontal right boundary Vertical lower boundary Vertical upper boundary Extract the horizontal left boundary of bounding box B. Horizontal right boundary Vertical lower boundary Vertical upper boundary To determine if two bounding boxes intersect, the logic is as follows: , , and If two bounding boxes intersect, they are determined to be non-intersecting; otherwise, they are determined not to intersect. The busbars corresponding to the intersecting bounding boxes are classified into the same continuous area. The above detection process is repeated until all busbar bounding boxes are traversed, so as to accurately define the boundary range of the power supply collection area at the sending end and the load center area at the receiving end, and ensure that the electrical connection of the busbars in the area is continuous and unbroken.

[0034] For inter-regional connection channels, the intersection relationship between the bounding boxes corresponding to the lines connecting different regional buses and the regional boundary bounding boxes is detected using the Axis Aligned Bounding Box (AABB) intersection detection algorithm. Specifically, the calculation process involves constructing a regional boundary bounding box for each defined region. The boundary range of the regional boundary bounding box is defined by the maximum lateral left boundary, minimum lateral right boundary, maximum vertical lower boundary, and minimum vertical upper boundary of all bus bounding boxes within that region. For all busbar enclosures within the area The minimum value, For all busbar enclosures within the area The maximum value, For all busbar enclosures within the area The minimum value, For all busbar enclosures within the area The maximum value; then construct a bounding box for each line connecting different area busbars, with the lateral boundary of the line bounding box being the bounding boxes of the two busbars at both ends. The minimum value to the two busbar enclosures The maximum value, with the vertical boundary being the bounding box of the two end busbars. The minimum value to the two busbar enclosures The maximum value; using the same bounding box intersection detection logic as above, it detects whether the line bounding box intersects with two different regional boundary bounding boxes at the same time. If they intersect at the same time, the line is determined to be a cross-regional line, and all such cross-regional intersecting line channels are selected as inter-regional connection channels; based on the power injection scale and electrical location importance of the bus in each region, the bus with the largest power injection scale and the most critical electrical connection is selected from the sending-end power collection area as the core bus of the sending-end power collection area, the bus with the largest load scale and the most prominent hub role is selected from the receiving-end load center area as the receiving-end load center hub bus, and the bus with the largest power exchange volume and the most core position is selected from the inter-regional connection channels as the key connection bus of the regional power grid interconnection. The three selected buses are jointly determined as three topology sensing base points.

[0035] Step 402: Connect the three topology sensing base points sequentially to construct a topology sensitive domain; divide the topology sensitive domain evenly into multiple non-overlapping electrical isopleths, specifically including: constructing axis-aligned bounding boxes for each of the three topology sensing base points, using the same method as the bus bounding box construction method in step 401, based on the coordinates of each topology sensing base point. The electrical influence radius is determined based on the rated voltage and centered on the voltage. This determines the lateral boundaries of the bounding box. Longitudinal boundary Then, using the outer boundaries of the three bounding boxes as a reference, the initial boundary range of the topology-sensitive domain is determined. The specific calculation process is as follows: extract all the horizontal left boundaries, horizontal right boundaries, vertical lower boundaries, and vertical upper boundaries of the three topology-sensing base point bounding boxes. The horizontal left boundary of the initial boundary is... The horizontal right boundary is The lower vertical boundary is The vertical upper boundary is A, B, and C correspond to the bounding boxes of the three topology-aware base points, thereby determining the initial boundary of the topology-sensitive domain.

[0036] Based on the actual equipment connection paths of the power grid, the core busbar of the sending-end power collection area is connected to the hub busbar of the receiving-end load center, the hub busbar of the receiving-end load center is connected to the key interconnection busbar of the regional power grid, and the key interconnection busbar of the regional power grid is connected to the core busbar of the sending-end power collection area, forming a complete and closed topology sensitive domain. The topology sensitive domain is uniformly partitioned according to the natural electrical partitions of the power grid and the equipment connection boundaries. The partitioning process incorporates the axis-aligned bounding box (AABB) intersection detection algorithm. The specific calculation and implementation process is as follows: First, the axis-aligned bounding box (AABB) intersection detection algorithm is used to divide the topology sensitive domain into an initial partitioned grid. The size of the grid is determined according to the density of equipment in the topology sensitive domain. The grid size is smaller in densely populated areas and larger in sparsely populated areas. The specific calculation method is based on the horizontal dimension of the grid. Grid vertical dimension ,in This represents the total horizontal length of the topology-sensitive domain. N is the total vertical length of the topology sensitive domain, and N is the number of preset grids. The number of preset grids is determined based on the total number of devices in the topology sensitive domain. The more devices there are, the more preset grids there are. The value usually ranges from 50 to 200.

[0037] After dividing the initial grid, an axis-aligned bounding box is constructed for each initial grid. The boundary range of the grid bounding box is completely consistent with the boundary of the initial grid. Then, based on the actual distribution of buses and lines, the distribution of axis-aligned bounding boxes corresponding to the equipment in each initial grid is detected. The detection process uses the same bounding box intersection detection logic as in step 401, i.e., determining... , , and The process involves determining whether mesh bounding boxes and device bounding boxes intersect, and counting the number and type of intersecting devices within each mesh. Mesh grids containing devices with similar electrical characteristics and whose bounding boxes do not overlap are merged. The merging process is as follows: for two adjacent initial meshes, if the device types in both meshes are of the same electrical characteristics (e.g., both are power-side buses and lines, or both are load-side buses and lines), and the device bounding boxes in the two meshes do not overlap, meaning that the device bounding boxes in one mesh do not meet the intersection condition with the device bounding boxes in the other mesh, then the two meshes are merged into a larger mesh. This merging process is repeated until all adjacent meshes cannot be merged, ultimately dividing the topology sensitive domain into multiple non-overlapping electrical isopleths with relatively independent electrical characteristics.

[0038] Step 403: Extract the voltage phase angle of all buses and the active power of all lines within each electrical equivalent block from the electrical measurement data. Calculate the average value of the bus voltage phase angle and the sum of the active power of the lines within each electrical equivalent block. Weight the average voltage phase angle and the sum of the active power corresponding to each electrical equivalent block to obtain the response weight of each electrical equivalent block. Specifically, this includes: first, locating the bounding box range corresponding to each electrical equivalent block using the axis-aligned bounding box (AABB) intersection detection algorithm. The boundary range of the electrical equivalent block bounding box is the maximum lateral left boundary, minimum lateral right boundary, maximum vertical lower boundary, and minimum vertical upper boundary of the bounding boxes of all equipment within the equivalent block. The calculation method is consistent with the region boundary bounding box calculation method in Step 401, i.e. , , , Next, extract the electrical measurement data of all buses and lines within this range. The extraction process is as follows: traverse the bounding boxes of all buses and lines in the power grid, and use the same bounding box intersection detection logic as in step 401 to determine whether the bounding box of each bus and line intersects with the bounding box of the electrical equivalent block. If they intersect, it is determined that the bus and line belong to the electrical equivalent block, and the corresponding electrical measurement data such as voltage phase angle and active power are extracted to ensure that the extracted data all belong to the electrical equivalent block and that no cross-block data is mixed in.

[0039] Calculate the average phase angle of the bus voltage and the sum of the active power of the lines within each electrical equivalent block. The calculation process involves summing the phase angle values ​​of the voltages of all buses within the electrical equivalent block, and then dividing by the total number of buses within the electrical equivalent block to obtain the average phase angle of the voltage for that electrical equivalent block. ,in Let n be the voltage phase angle of a single busbar, and n be the total number of buses within the equivalent block. The active power values ​​of all lines within the electrical equivalent block are summed sequentially to obtain the total active power of that electrical equivalent block. ,in Let m be the active power of a single line and m be the total number of lines within the equivalent block. The average voltage phase angle and the sum of active power corresponding to each electrical equivalent block are weighted and combined. An axis-aligned bounding box (AABB) intersection detection algorithm is incorporated into the weighting process to verify the accuracy of the electrical equivalent block boundaries. Specifically, the calculation and implementation process involves iterating through all busbar and line bounding boxes again, checking their intersection with the corresponding electrical equivalent block bounding boxes, and simultaneously checking whether the busbar or line is contained within the bounding boxes of other electrical equivalent blocks. If a device bounding box intersects with two or more electrical equivalent block bounding boxes simultaneously, it is determined that there is a deviation in the equivalent block boundary, and the boundary of the equivalent block bounding boxes needs to be readjusted. This boundary adjustment and detection process is repeated until all device bounding boxes intersect with only one electrical equivalent block bounding box, ensuring that no cross-block omissions or duplications of the data involved in the calculation are observed. After the boundary verification is correct, the average voltage phase angle is multiplied by a preset phase angle weight, and the sum of active power is multiplied by a preset power weight. The two calculation results are then added sequentially to obtain the response weight of each electrical equivalent block. ,in For phase angle weights, Power weight.

[0040] This embodiment accurately defines the region boundary, divides the electrical equivalent block mesh, and verifies the accuracy of the equivalent block boundary by calculating the bounding box boundary of the device and region, detecting the intersection relationship of the bounding boxes, thus ensuring that the data extraction is complete and without duplication.

[0041] In a preferred embodiment of the present invention, step 5, characterized in that calculating and analyzing the reliable topology state and response weights to obtain the key transmission section, may include: Step 501: Based on the device connection relationships in the trusted topology state, identify all transmission lines connecting different electrical equivalence blocks within the topology sensitive domain, and treat each transmission line as a candidate transmission section. Specifically, this includes: calling all device connection relationship data stored in the trusted topology state, which contains connection node information and connection status of all buses, transmission lines, and switching equipment within the topology sensitive domain; traversing all transmission lines within the topology sensitive domain; checking the connection nodes at both ends of each transmission line one by one; determining which electrical equivalence block each bus connected to at both ends of each transmission line belongs to; the judgment criterion is which electrical equivalence block's bounding box the bus intersects with; if they intersect, the bus belongs to that electrical equivalence block; if the buses connected to both ends of a transmission line belong to two different electrical equivalence blocks (i.e., the electrical equivalence block identifiers corresponding to the two buses are different), then the transmission line is determined to be a transmission line connecting different electrical equivalence blocks, and this transmission line is treated as an independent candidate transmission section.

[0042] Step 502: Based on the response weight of each electrical equivalent block, the response weights of the electrical equivalent blocks traversed by each candidate transmission section are summed to calculate the comprehensive weight. Specifically, this includes: retrieving the response weights of all electrical equivalent blocks calculated in step 403, establishing a correspondence between the response weights and the electrical equivalent block identifiers for quick lookup; for each candidate transmission section, reconfirming the electrical equivalent blocks traversed by the candidate transmission section, i.e., the two electrical equivalent blocks to which the busbars at both ends of the transmission line belong, querying the corresponding two response weights through the electrical equivalent block identifiers, and summing these two response weights. The calculation process is to add the response weight of the first electrical equivalent block to the response weight of the second electrical equivalent block, and the sum obtained is the comprehensive weight corresponding to the candidate transmission section.

[0043] Step 503: Compare the comprehensive weight value with a preset weight threshold, and select candidate transmission sections whose comprehensive weight value is greater than the preset weight threshold to form a preliminary screening section set. Specifically, the preset weight threshold is determined based on the safety requirements of power grid operation, the importance of topology sensitive areas, and historical operating data, with a value range of 0.6 to 0.8. For core topology sensitive areas, the value is 0.7 to 0.8, and for general topology sensitive areas, the value is 0.6 to 0.7. The preset weight threshold is a fixed value stored in the system in advance. The preset weight threshold is retrieved, and the comprehensive weight value corresponding to each candidate transmission section is compared with the preset weight threshold one by one. The judgment process is to check whether the comprehensive weight value of the candidate transmission section is greater than the preset weight threshold. If the comprehensive weight value is greater than the preset weight threshold, the candidate transmission section is retained. If the comprehensive weight value is less than or equal to the preset weight threshold, the candidate transmission section is removed. After all candidate transmission sections have been compared, all the retained candidate transmission sections are integrated together to form a preliminary screening section set.

[0044] Step 504: Perform power flow calculation for each candidate transmission section to obtain the actual transmission power of each candidate transmission section. Combine this with the preset transmission limit of each candidate transmission section to calculate the load factor. Candidate transmission sections with a load factor greater than the preset load factor threshold are identified as critical transmission sections. Specifically, this includes: retrieving equipment connection relationships and electrical measurement data from the trusted topology state, using these data as input parameters for power flow calculation, and performing power flow calculation using the Newton-Raphson method. The specific implementation process of this method is as follows: set the initial voltage amplitude and phase angle of each node in the power grid, where the initial voltage amplitude of the PQ node is set to the rated voltage and the initial phase angle to 0°, and the PV node... The initial voltage amplitude is set to the rated voltage and the initial phase angle to 0°. The initial voltage amplitude and initial phase angle of the balancing node are also set to the rated voltage and 0°. A node admittance matrix is ​​constructed based on the equipment connection relationships. Each element in the node admittance matrix represents the admittance value between corresponding nodes. Diagonal elements represent the sum of the admittances of all connected branches of that node, and off-diagonal elements represent the negative values ​​of the branch admittances between the corresponding two nodes. Based on the power injection data in the electrical measurement data, a node power balance relationship is established, clarifying the balance between the active and reactive power injection values ​​of each node's power supply and the active and reactive power consumption values ​​of the load, ensuring that the node's power input and output remain balanced. A power balance relationship is established. The calculation relationship for power imbalance is established, calculating the active power imbalance and reactive power imbalance at each node. The active power imbalance is the difference between the actual active power injection and consumption at the node, minus the active power value calculated based on the node admittance matrix and current voltage parameters. The reactive power imbalance is calculated similarly. A Jacobi matrix is ​​constructed, with its elements calculated based on the partial derivatives of the power balance relationship with respect to voltage amplitude and phase angle. It is divided into four sub-matrices, corresponding to the partial derivatives of active power with respect to phase angle, active power with respect to voltage amplitude, reactive power with respect to phase angle, and reactive power with respect to voltage amplitude, respectively. The Jacobi matrix equations are solved, and the expression for the Jacobi matrix equations is J×ΔX. =-△PQ, where J is the Jacobian matrix, △X is the node voltage parameter correction vector, including the voltage phase angle correction and voltage magnitude correction for each node, and △PQ is the node power imbalance vector, including the active power imbalance and reactive power imbalance for each node. Solving this system of equations yields the corrections for the voltage magnitude and phase angle for each node. These corrections are then superimposed onto the current voltage magnitude and phase angle, completing one iteration. The process of calculating imbalances, constructing the Jacobian matrix, solving for corrections, and updating parameters is repeated until the active power imbalance and reactive power imbalance for all nodes are less than a preset error threshold. The preset error threshold ranges from [value missing]. After the iteration, the actual transmission power of each candidate transmission section is extracted; the preset transmission limit of each candidate transmission section is retrieved. This preset transmission limit is the minimum value between the thermal stability limit and the dynamic stability limit of the transmission line itself, and is stored in the system in advance. The load rate of each candidate transmission section is calculated by dividing the actual transmission power of the candidate transmission section by the preset transmission limit of that candidate transmission section to obtain the corresponding load rate; a preset load rate threshold is retrieved. This threshold is determined according to the requirements for safe and stable operation of the power grid, and its value range is 0. The load rate is set from 0.8 to 0.9 for core and critical transmission section candidates, and from 0.8 to 0.85 for general candidates. The load rate of each candidate transmission section is compared with the preset load rate threshold. If the load rate is greater than the preset load rate threshold, the candidate transmission section is determined to be a critical transmission section. If the load rate is less than or equal to the preset load rate threshold, the candidate transmission section is removed from the initial screening section set. Finally, all transmission lines determined to be critical transmission sections are integrated together to form a critical transmission section set.

[0045] This embodiment combines trusted topology states with response weights to perform hierarchical screening and power flow calculations on key transmission sections. This enables accurate identification of core transmission channels in the power grid that play a decisive role in safe and stable operation, avoids interference from irrelevant lines, and improves the accuracy and reliability of key transmission section identification.

[0046] In a preferred embodiment of the present invention, step 6, calculating the dynamic control limit value based on the key transmission section, combined with the reliable topology state, response weights, and electrical measurement data, may include: Step 601: Obtain all transmission lines constituting the critical transmission section and their connection relationships from the critical transmission section, and extract the static transmission limit parameters of each transmission line from the trusted topology state to obtain the static limit value. Specifically, this includes: retrieving the set of critical transmission sections determined in step 504, extracting the transmission lines contained in each critical transmission section one by one, clarifying the identifier, model, and connection bus information at both ends of each transmission line, sorting out all transmission lines constituting the critical transmission section and their complete connection relationships, ensuring no line omissions and no connection errors; retrieving the static transmission limit parameters of each transmission line stored in the trusted topology state, which includes data such as the long-term allowable transmission power, thermal stability limit, and dynamic stability limit of the transmission line; for each transmission line constituting the critical transmission section, extracting its corresponding long-term allowable transmission power and thermal stability limit, and determining the smaller value as the static limit value corresponding to the transmission line; performing the above extraction, comparison, and determination operations on each transmission line in sequence to obtain the static limit values ​​corresponding to all transmission lines constituting the critical transmission section.

[0047] Step 602: Based on the response weights, normalize the response weights of the electrical equivalent blocks traversed by the critical transmission section to obtain the weight coefficients of each electrical equivalent block. Specifically, this includes: identifying the electrical equivalent blocks traversed by the critical transmission section, i.e., the electrical equivalent blocks to which the busbars at both ends of each transmission line constituting the critical transmission section belong; integrating all electrical equivalent blocks traversed by the critical transmission section; removing duplicate electrical equivalent blocks to obtain a set of electrical equivalent blocks related to the critical transmission section; retrieving the response weights corresponding to these electrical equivalent blocks calculated in step 403; and statistically analyzing the minimum and maximum values ​​among these response weights. The response weights of each electrical equivalent block are normalized. Specifically, the response weight of the electrical equivalent block is subtracted from the minimum response weight of all related electrical equivalent blocks to obtain the first calculation result. Then, the minimum response weight of all related electrical equivalent blocks is subtracted from the maximum response weight to obtain the second calculation result. The first calculation result is divided by the second calculation result, and the resulting value is the weight coefficient corresponding to the electrical equivalent block. After normalization, all weight coefficients are within the range of zero to one. The above calculation operation is performed on each related electrical equivalent block in turn to obtain the weight coefficients corresponding to all electrical equivalent blocks.

[0048] Step 603: Extract the active power of each transmission line in the key transmission section from the electrical measurement data; calculate the load rate of each transmission line by combining the static limit value of each transmission line; and perform weighted correction on the static limit value according to the weight coefficient of each electrical equivalent block to obtain the dynamic correction coefficient of each transmission line. Specifically, this includes: retrieving electrical measurement data; extracting the real-time active power data corresponding to each transmission line according to the identification of each transmission line in the key transmission section, ensuring that the extracted data corresponds one-to-one with the transmission line and there is no data confusion; and calculating the load rate of each transmission line by combining the static limit value of each transmission line obtained in step 601. The load factor is calculated by dividing the active power of each transmission line by the corresponding static limit value. The electrical equivalent blocks traversed by each transmission line are identified, and the weighting coefficients corresponding to these blocks are retrieved. The static limit value of the transmission line is then weighted and corrected by multiplying the static limit value by the corresponding weighting coefficient of the electrical equivalent block. The resulting value is the dynamic correction coefficient for that transmission line. This extraction, calculation, and correction process is repeated for each transmission line constituting a critical transmission section to obtain the load factor and dynamic correction coefficient for all transmission lines.

[0049] Step 604 involves calculating the load rate and dynamic correction coefficient of each transmission line to obtain the dynamic control limit value. Specifically, this includes retrieving the load rate and dynamic correction coefficient of each transmission line obtained in step 603, as well as the static limit value obtained in step 601. The dynamic control limit value is calculated for each transmission line by multiplying the static limit value of the transmission line by the dynamic correction coefficient to obtain the first calculation result. Then, the first calculation result is divided by the load rate of the transmission line. The final value obtained is the dynamic control limit value corresponding to the transmission line. The dynamic control limit value can be adjusted in real time according to changes in the power grid topology and load transfer to ensure that the dynamic control limit value matches the actual operating state of the power grid. The above calculation operation is performed sequentially on each transmission line constituting a key transmission section to obtain the dynamic control limit value corresponding to all transmission lines.

[0050] This embodiment calculates dynamic control limit values ​​based on key transmission sections, reliable topology states, response weights, and electrical measurement data. This enables control indicators to closely follow changes in the actual operating state of the power grid, overcoming the inability to adapt to topology changes and load transfers, and improving the flexibility and targeting of power grid control.

[0051] In a preferred embodiment of the present invention, step 7, generating and issuing control adjustment commands based on dynamic control limit values ​​to ensure the safe and stable operation of the power grid, may include: Step 701: Obtain the upper limit of power transmission for the critical transmission section from the dynamic control limit values, and extract the active power of each transmission line constituting the critical transmission section from the electrical measurement data. Calculate the actual transmission power of the critical transmission section based on the active power of each transmission line. Specifically, this includes: retrieving the set of dynamic control limit values ​​obtained in step 604, where the dynamic control limit values ​​are the upper limit of power transmission for each transmission line; integrating the upper limits of power transmission for all transmission lines constituting each critical transmission section to clarify the range of the upper limit of power transmission for each critical transmission section; retrieving electrical measurement data, extracting the current active power data of each transmission line based on the identifier of each transmission line constituting the critical transmission section to ensure the real-time performance and accuracy of the data; and calculating the actual transmission power of each critical transmission section by sequentially adding the active power of all transmission lines constituting the critical transmission section, with the sum being the actual transmission power of the critical transmission section.

[0052] Step 702: Compare the actual transmission power of the key transmission section with the upper limit of power transmission to calculate the power transmission margin; compare the power transmission margin with a preset warning threshold. If the power transmission margin is lower than the preset warning threshold, it is determined that there is a risk of exceeding the limit in the power grid operation, triggering control adjustment requirements. Specifically, this includes: for each key transmission section, subtracting its actual transmission power from the upper limit of power transmission for that key transmission section to obtain the power transmission margin of that key transmission section. The power transmission margin reflects the remaining transmission capacity of the key transmission section; retrieve the preset warning threshold, which is determined based on the power grid safety and stability operation standards and the importance of the key transmission section. The value ranges from 5% to 15% of the upper limit of power transmission for critical transmission sections, 5% to 10% for core transmission sections, and 10% to 15% for general transmission sections. This value is pre-stored in the system. The power transmission margin of each critical transmission section is compared with the preset warning threshold. The judgment process involves checking whether the power transmission margin is lower than the preset warning threshold. If the power transmission margin is lower than the preset warning threshold, it indicates that the remaining transmission capacity of the critical transmission section is insufficient, and the grid operation status is at risk of exceeding limits, immediately triggering control adjustment requirements. If the power transmission margin is greater than or equal to the preset warning threshold, it indicates that the critical transmission section is operating normally, and no control adjustment requirements are needed.

[0053] Step 703: Generate corresponding control adjustment commands based on the power transmission margin. These commands include one or more combinations of adjusting generator active power output, adjusting transformer tap positions, switching reactive power compensation equipment, or disconnecting interruptible loads. Specifically, for each critical transmission section with a risk of exceeding limits, determine the intensity of the control adjustment based on its power transmission margin; the smaller the power transmission margin, the greater the control adjustment intensity. The weight ranges for each control adjustment command method are as follows: generator active power output adjustment weight ranges from 0.6 to 0.8; reactive power compensation equipment switching weight ranges from 0.1 to 0.2; transformer tap position adjustment weight ranges from 0.05 to 0.1; and interruptible load disconnection weight ranges from 0.05 to 0.1. The sum of all weights is 1. The weights of each adjustment method are dynamically allocated according to the degree of power transmission margin deficiency. The closer the power transmission margin is to the lower limit of the warning threshold, the greater the weight of generator active power output adjustment. The interruptible load shedding weight is only activated when the power transmission margin is severely insufficient. If the power transmission margin is slightly lower than the warning threshold, control adjustment commands to adjust generator active power output are generated first. Specifically, the active power output of generators on the sending end of key transmission sections is adjusted to reduce the power output on the sending end and reduce the power transmission pressure on key transmission sections. If the power transmission margin is significantly lower than the warning threshold, a combination command to adjust generator active power output and switch reactive power compensation equipment is generated. While reducing the active power output of generators on the sending end, reactive power compensation equipment along key transmission sections is switched to improve grid voltage stability and reduce power loss. If the power transmission margin is severely lower than the warning threshold, a combination of multiple control adjustment commands is generated, including adjusting generator active power output, adjusting transformer tap positions, switching reactive power compensation equipment, and shedding some interruptible loads.

[0054] Step 704 involves issuing and executing control adjustment commands. By adjusting grid operating parameters, the actual transmission power of key transmission sections is restored to within the safe range of the power transmission upper limit to ensure the safe and stable operation of the grid. Specifically, this includes: encoding the control adjustment commands generated in step 703 according to a preset communication protocol to ensure no data loss or errors occur during command transmission; and issuing the encoded control adjustment commands to the corresponding execution equipment, including generators, transformers, reactive power compensation equipment, and load control devices, through the grid dispatch and control system. After issuance, the receiving status and execution progress of the commands are monitored in real time. If a command is not executed... In the event of a failure to receive or execute the command, the command should be reissued immediately, and the cause of the fault should be investigated. During the execution of the command, electrical measurement data should be collected in real time to monitor the actual transmission power changes of key transmission sections and determine whether the actual transmission power has gradually recovered to within the safe range of the upper limit of power transmission. If the actual transmission power has recovered to the safe range, subsequent adjustment operations should be stopped. If the actual transmission power has not recovered to the safe range, the adjustment amount of the control adjustment command should be adjusted according to the real-time monitoring data, and the command should be reissued and executed until the actual transmission power of the key transmission section has recovered to within the safe range of the upper limit of power transmission, ensuring that the power grid is always in a safe and stable operating state.

[0055] This embodiment generates and issues targeted control adjustment commands, accurately matches the adjustment intensity according to the power transmission margin, can quickly alleviate the power transmission pressure of key transmission sections, eliminate the risk of grid operation exceeding limits in a timely manner, ensure the safe and stable operation of the grid in scenarios such as load transfer and topology changes, and improve the grid's anti-disturbance capability and operational reliability.

[0056] like Figure 2 As shown, embodiments of the present invention also provide a topology evolution-aware dynamic adjustment system for grid section control limits, comprising: The acquisition module is used to acquire synchronous phasor status data of power grid feeders, preprocess the synchronous phasor status data of power grid feeders to obtain a time-series data stream, which includes equipment status signals and electrical measurement data. The update module is used to identify the status change events of circuit breakers and disconnectors based on the equipment status signals and the preset initial topology connection relationship, and update the initial topology connection relationship according to the status change events to obtain the real-time topology status. The verification module is used to calculate and generate a reliable cross section based on the real-time topology status and electrical measurement data, and to verify the reliable cross section to obtain the reliable topology status. The calculation module is used to select the core bus of the power collection area at the sending end, the hub bus of the load center at the receiving end, and the key interconnection bus of the regional power grid as three topology sensing base points in the power grid according to the reliable topology state. The topology sensing base points are connected to form a topology sensitive domain. The topology sensitive domain is divided into multiple electrical equivalent blocks. The response weight is calculated based on the bus voltage phase angle and line active power in each electrical equivalent block. The analysis module is used to calculate and analyze the reliable topology state and response weights to obtain the key transmission sections; The processing module is used to calculate the dynamic control limit value based on the key transmission section, combined with the reliable topology state, response weights and electrical measurement data; The output module is used to generate and issue control adjustment commands based on dynamic control limit values ​​to ensure the safe and stable operation of the power grid.

[0057] It should be noted that this system is a system corresponding to the above method. All implementation methods in the above method embodiments are applicable to this embodiment and can achieve the same technical effect.

[0058] Embodiments of the present invention also provide a computing device, including: a processor and a memory storing a computer program, wherein the computer program, when executed by the processor, performs the method described above. All implementations in the above method embodiments are applicable to this embodiment and can achieve the same technical effects.

[0059] 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 should also be considered within the scope of protection of the present invention.

Claims

1. A method for dynamic adjustment of grid section control limits based on topology evolution sensing, characterized in that, The method includes: Step 1: Collect the synchronous phasor status data of the power grid feeder, preprocess the synchronous phasor status data of the power grid feeder to obtain the time-series data stream, which includes equipment status signals and electrical measurement data; Step 2: Based on the equipment status signal and the preset initial topology connection relationship, identify the status change events of the circuit breaker and disconnector, and update the initial topology connection relationship according to the status change events to obtain the real-time topology status. Step 3: Calculate and generate a reliable cross section based on the real-time topology status and electrical measurement data, and verify the reliable cross section to obtain the reliable topology status; Step 4: Based on the reliable topology state, select the core bus of the power collection area at the sending end, the hub bus of the load center at the receiving end, and the key interconnection bus of the regional power grid as three topology sensing base points in the power grid. The topology sensing base points are connected to form a topology sensitive domain. The topology sensitive domain is divided to obtain multiple electrical equivalent blocks. The response weight is calculated based on the bus voltage phase angle and line active power in each electrical equivalent block. Step 5: Calculate and analyze the trusted topology state and response weights to obtain the key transmission sections; Step 6: Based on the key transmission sections, combined with the reliable topology state, response weights, and electrical measurement data, calculate the dynamic control limit values. Step 7: Generate and issue control adjustment commands based on the dynamic control limit values ​​to ensure the safe and stable operation of the power grid.

2. The method for dynamic adjustment of grid section control limits based on topology evolution sensing according to claim 1, characterized in that, Collect grid feeder synchronization phasor status data, preprocess the grid feeder synchronization phasor status data to obtain a time-series data stream, which includes equipment status signals and electrical measurement data, including: Collect grid feeder synchronous phasor status data, which includes grid status signals, synchronization phasor data, and feeder data. Among them, the grid status signals include the status information of circuit breakers and disconnectors, the synchronization phasor data includes the bus voltage amplitude, bus voltage phase angle, line active power, and line reactive power, and the feeder data includes feeder active power and feeder reactive power. The power grid status signal, synchronization phasor data, and feeder data are time-synchronized to obtain time-aligned synchronization data. The time-aligned synchronization data is then filtered to obtain clean data. The clean data is then normalized to obtain normalized data. The portion of the normalized data corresponding to the power grid status signal is reconstructed to obtain the equipment status signal. The portion of the normalized data corresponding to the synchronization phasor data and feeder data is then reconstructed to obtain electrical measurement data. The electrical measurement data includes bus voltage amplitude, bus voltage phase angle, line active power, line reactive power, feeder active power, and feeder reactive power.

3. The method for dynamic adjustment of grid cross-section control limits based on topology evolution sensing according to claim 2, characterized in that, Based on the equipment status signals and the preset initial topology connection relationship, the system identifies the status change events of circuit breakers and disconnectors, updates the initial topology connection relationship according to the status change events, and obtains the real-time topology status, including: The status information of circuit breakers and disconnectors in the equipment status signal is compared with the corresponding equipment status in the preset initial topology connection relationship. Circuit breakers and disconnectors that have changed status are detected and status change events are identified. Based on the state change event, the corresponding device state in the preset initial topology connection relationship is modified to obtain the updated topology connection relationship; the updated topology connection relationship is then subjected to connectivity analysis and verification to obtain the real-time topology status.

4. The method for dynamic adjustment of power grid cross-section control limits based on topology evolution sensing according to claim 3, characterized in that, Based on real-time topology status and electrical measurement data, a reliable profile is calculated and generated, and the reliable profile is verified to obtain the reliable topology status, including: Obtain device connection relationships from real-time topology status, and extract bus voltage amplitude, bus voltage phase angle, line active power, line reactive power, feeder active power, and feeder reactive power from electrical measurement data; assemble the device connection relationships with electrical measurement data to obtain an initial profile containing device connection status, electrical measurement values, and measurement directions; Based on the equipment connection relationship, the voltage phase angle difference is calculated using the bus voltage phase angle and compared with the line active power to obtain the first comparison result; based on the equipment connection relationship, the injected power is calculated using the line active power and line reactive power and compared with the feeder active power and feeder reactive power to obtain the second comparison result; based on the two comparison results, abnormal measurement data exceeding the preset threshold are identified. The abnormal measurement data is corrected and calculated to obtain the updated cross section. The device connection status in the updated cross section is compared with the real-time topology status. If the two are consistent, the updated cross section is taken as the reliable cross section, and the reliable topology status is obtained based on the topology status confirmed in the reliable cross section.

5. The method for dynamic adjustment of power grid cross-section control limits based on topology evolution sensing according to claim 4, characterized in that, Step 4 includes: Based on the device connection relationships and electrical measurement data contained in the trusted topology state, the sending-end power collection area, the receiving-end load center area, and the inter-regional interconnection channel are identified from the power grid. Based on the power injection scale or electrical location importance of the bus in each area, a core bus is selected from the sending-end power collection area as the core bus of the sending-end power collection area, a hub bus is selected from the receiving-end load center area as the hub bus of the receiving-end load center, and a key interconnection bus is selected from the inter-regional interconnection channel as the key interconnection bus of the regional power grid interconnection. The three selected buses are determined as three topology sensing base points. Three topology sensing base points are connected sequentially to construct a topology sensing domain; the topology sensing domain is then uniformly divided into multiple non-overlapping electrical isobars. The voltage phase angle of all buses and the active power of all lines within each electrical equivalent block are extracted from the electrical measurement data. The average value of the voltage phase angle of the buses and the sum of the active power of the lines within each electrical equivalent block are calculated. The average value of the voltage phase angle and the sum of the active power of each electrical equivalent block are weighted and combined to obtain the response weight of each electrical equivalent block.

6. The method for dynamic adjustment of grid section control limits based on topology evolution sensing according to claim 5, characterized in that, By calculating and analyzing the reliable topology state and response weights, key transmission sections are obtained, including: Based on the device connection relationships in the trusted topology state, identify all transmission lines connecting different electrical equivalent blocks within the topology sensitive domain, and treat each transmission line as a candidate transmission section; Based on the response weight of each electrical equivalent block, the response weights of the electrical equivalent blocks traversed by each candidate transmission section are summed to calculate the comprehensive weight. The comprehensive weight value is compared with the preset weight value threshold, and candidate transmission sections with comprehensive weight values ​​greater than the preset weight value threshold are selected to form a preliminary set of selected sections. Power flow calculations are performed on each candidate transmission section to obtain the actual transmission power of each candidate transmission section. The load rate is calculated in combination with the preset transmission limit of each candidate transmission section. Candidate transmission sections with a load rate greater than the preset load rate threshold are identified as key transmission sections.

7. The method for dynamic adjustment of grid section control limits based on topology evolution sensing according to claim 6, characterized in that, Based on the key transmission sections, combined with the reliable topology state, response weights, and electrical measurement data, the dynamic control limit values ​​are calculated, including: All transmission lines constituting the critical transmission section and their connection relationships are obtained from the critical transmission section, and the static transmission limit parameters of each transmission line are extracted from the reliable topology state to obtain the static limit value. Based on the response weights, the response weights of the electrical equivalent blocks traversed by the key transmission section are normalized to obtain the weight coefficients of each electrical equivalent block. The active power of each transmission line in the key transmission section is extracted from the electrical measurement data. Combined with the static limit value of each transmission line, the load rate of each transmission line is calculated. According to the weight coefficient of each electrical equivalent block, the static limit value is weighted and corrected to obtain the dynamic correction coefficient of each transmission line. The load rate and dynamic correction coefficient of each transmission line are calculated to obtain the dynamic control limit value.

8. The method for dynamic adjustment of grid section control limits based on topology evolution sensing according to claim 7, characterized in that, Based on the dynamic control limit values, control adjustment commands are generated and issued to ensure the safe and stable operation of the power grid, including: The upper limit of power transmission of the key transmission section is obtained from the dynamic control limit value, and the active power of each transmission line constituting the key transmission section is extracted from the electrical measurement data. The actual transmission power of the key transmission section is calculated based on the active power of each transmission line. The actual transmission power of the key transmission section is compared with the upper limit of power transmission to calculate the power transmission margin. The power transmission margin is then compared with a preset warning threshold. If the power transmission margin is lower than the preset warning threshold, it is determined that there is a risk of exceeding the limit in the power grid operation state, triggering the need for control adjustment. Based on the magnitude of the power transmission margin, corresponding control adjustment commands are generated; the control adjustment commands include one or more combinations of adjusting the generator active power output, adjusting the transformer tap position, switching on or off reactive power compensation equipment, or disconnecting interruptible loads. The control and adjustment instructions are issued and executed. By adjusting the power grid operating parameters, the actual transmission power of key transmission sections is restored to within the safe range of the upper limit of power transmission, so as to ensure the safe and stable operation of the power grid.

9. A topology-evolution-aware dynamic adjustment system for grid section control limits, wherein the system implements the method as described in any one of claims 1 to 8, characterized in that, include: The acquisition module is used to acquire synchronous phasor status data of power grid feeders, preprocess the synchronous phasor status data of power grid feeders to obtain a time-series data stream, which includes equipment status signals and electrical measurement data. The update module is used to identify the status change events of circuit breakers and disconnectors based on the equipment status signals and the preset initial topology connection relationship, and update the initial topology connection relationship according to the status change events to obtain the real-time topology status. The verification module is used to calculate and generate a reliable cross section based on the real-time topology status and electrical measurement data, and to verify the reliable cross section to obtain the reliable topology status. The calculation module is used to select the core bus of the power collection area at the sending end, the hub bus of the load center at the receiving end, and the key interconnection bus of the regional power grid as three topology sensing base points in the power grid according to the reliable topology state. The topology sensing base points are connected to form a topology sensitive domain. The topology sensitive domain is divided into multiple electrical equivalent blocks. The response weight is calculated based on the bus voltage phase angle and line active power in each electrical equivalent block. The analysis module is used to calculate and analyze the reliable topology state and response weights to obtain the key transmission sections; The processing module is used to calculate the dynamic control limit value based on the key transmission section, combined with the reliable topology state, response weights and electrical measurement data; The output module is used to generate and issue control adjustment commands based on dynamic control limit values ​​to ensure the safe and stable operation of the power grid.

10. A computing device, characterized in that, include: One or more processors; A storage device for storing one or more programs, which, when executed by one or more processors, cause the one or more processors to implement the method as described in any one of claims 1 to 8.

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