A method, apparatus, and article of manufacture for performing a prospective fault scan on an element of an electric power system
By calculating the node susceptance matrix and active power flow increment in the power system, and combining graph parallel computing and superposition principles, the severity of anticipated faults can be quickly assessed. This solves the problem of low efficiency in traditional methods, achieves efficient fault scanning, and significantly improves the calculation speed.
Patent Information
- Authority / Receiving Office
- CN · China
- Patent Type
- Patents(China)
- Current Assignee / Owner
- CHINA SOUTHERN POWER GRID ARTIFICIAL INTELLIGENCE TECHNOLOGY CO LTD
- Filing Date
- 2024-12-03
- Publication Date
- 2026-05-29
AI Technical Summary
Traditional methods of predicting faults are inefficient in power systems and struggle to cope with the ever-expanding scale of power systems and the increasing number of predicted faults, resulting in heavy emergency costs.
By obtaining the nodal susceptance matrix of the component under the expected fault condition, the total increment of active power flow is determined, the voltage phase angle increment and reactance value are calculated, the severity index calculation model is used to evaluate the severity of the expected fault, and rapid fault scanning is achieved by combining graph parallel computing and superposition principles.
It shortens the detailed power flow calculation time, improves the efficiency of anticipated fault scanning, increases the calculation speed by 13 times, and enables the 10,000-level bus system to complete 100 fault scans within 3 seconds. The average calculation time for the main network and main distribution network systems is reduced to 0.15 milliseconds and 0.375 milliseconds, respectively.
Smart Images
Figure CN119335323B_ABST
Abstract
Description
Technical Field
[0001] This application relates to the field of power grid safety monitoring technology, and in particular to a method, apparatus, computer equipment, storage medium and computer program product for predicting faults in power system components. Background Technology
[0002] As the power grid continues to expand, the types of faults that may occur also increase, necessitating the classification of different fault forms based on various conditions or criteria. In the era before network analysis capabilities were available, power system safety measures primarily focused on ensuring sufficient spinning reserves, resulting in heavy emergency costs.
[0003] In traditional technologies, calculating power flow by computer improves the ability of network security analysis. That is, the power flow calculated for a fault is a fault analysis. Early anticipatory fault analysis used AC power flow and tributary power flow to continuously calculate the power flow solutions of various fault scenarios in the set of anticipatory faults in order to determine its impact on the safe operation of the system. However, this approach has the drawback of low fault scanning efficiency and is difficult to cope with the ever-expanding scale of power systems and the increasing number of anticipatory faults. Summary of the Invention
[0004] Therefore, it is necessary to provide a method, apparatus, computer equipment, computer-readable storage medium, and computer program product for predicting faults in power system components, addressing the aforementioned technical problems.
[0005] Firstly, this application provides a method for predictive fault scanning applied to power system components. The method includes:
[0006] Obtain the node susceptance matrix of the component under test under the expected fault condition, determine the total active power flow increment of the component under test under the expected fault condition, and obtain the voltage phase angle increment corresponding to each bus in the component under test based on the node susceptance matrix and the total active power flow increment.
[0007] For each branch in the element under test, determine the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch;
[0008] The active power flow increment of the current branch is obtained based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch.
[0009] The active power flow of the current branch is obtained based on the ground state power flow and the active power flow increment of the current branch.
[0010] Determine the weighting coefficient and power flow limit value of the current branch, and input the active power flow, weighting coefficient and power flow limit value into a preset severity index calculation model to obtain the expected fault severity index when the current branch is disconnected.
[0011] In one embodiment, obtaining the nodal susceptance matrix of the element under test under a anticipated fault condition includes:
[0012] Determine the initial matrix corresponding to the ground state power flow of the current branch; based on the initial matrix, obtain the matrix after the ground state power flow changes under the expected fault condition; use the matrix correction method to correct the changed matrix to obtain the node susceptance matrix of the element under test under the expected fault condition.
[0013] In one embodiment, obtaining the voltage phase angle increment corresponding to each bus in the element under test based on the node susceptance matrix and the total active power flow increment includes:
[0014] The node susceptance matrix and the total active power flow increment are input into a preset voltage phase angle increment matrix operation model to obtain the voltage phase angle increment matrix of the component under test under the expected fault condition; based on the voltage phase angle increment matrix, the voltage phase angle increment corresponding to each bus in the component under test is determined.
[0015] In one embodiment, determining the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch includes:
[0016] Determine the first bus and the second bus corresponding to the current branch; take the voltage phase angle increment of the first bus as the first voltage phase angle increment, and take the voltage phase angle increment of the second bus as the second voltage phase angle increment; obtain the reactance value of the current branch based on the first bus and the second bus.
[0017] In one embodiment, obtaining the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch includes:
[0018] Based on the first voltage phase angle increment and the second voltage phase angle increment, the voltage phase angle increment difference corresponding to the first voltage phase angle increment and the second voltage phase angle increment is obtained; the voltage phase angle increment difference and the reactance value are input into a preset active power flow increment calculation model to obtain the active power flow increment of the current branch.
[0019] In one embodiment, determining the total active power flow increment of the component under anticipated fault conditions includes:
[0020] Obtain the vector of the voltage phase angle of each node in the element to be detected; input the vector of the voltage phase angle of each node in the element to be detected into a preset active power flow total increment calculation model to obtain the total active power flow increment.
[0021] Secondly, this application also provides a predictive fault scanning device for power system components. The device includes:
[0022] The phase angle increment module is used to obtain the node susceptance matrix of the component under test under the expected fault condition, determine the total active power flow increment of the component under test under the expected fault condition, and obtain the voltage phase angle increment corresponding to each bus in the component under test based on the node susceptance matrix and the total active power flow increment.
[0023] The reactance calculation module is used to determine the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch for each branch in the element under test.
[0024] The power flow increment module is used to obtain the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value.
[0025] The active power flow module is used to obtain the active power flow of the current branch based on the ground state power flow and the active power flow increment of the current branch.
[0026] The index determination module is used to determine the weight coefficient and power flow limit value of the current branch, and input the active power flow, weight coefficient and power flow limit value into a preset severity index calculation model to obtain the expected fault severity index when the current branch is disconnected.
[0027] Thirdly, this application also provides a computer device. The computer device includes a memory and a processor, the memory storing a computer program, and the processor executing the computer program to perform the following steps:
[0028] Obtain the node susceptance matrix of the component under test under the anticipated fault condition, determine the total active power flow increment of the component under test under the anticipated fault condition, and obtain the voltage phase angle increment corresponding to each bus in the component under test based on the node susceptance matrix and the total active power flow increment. For each branch in the component under test, determine the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. Obtain the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. Obtain the active power flow of the current branch based on the ground state power flow and the active power flow increment. Determine the weighting coefficient and power flow limit value of the current branch, and input the active power flow, weighting coefficient, and power flow limit value into a preset severity index calculation model to obtain the anticipated fault severity index when the current branch is disconnected.
[0029] Fourthly, this application also provides a computer-readable storage medium. The computer-readable storage medium stores a computer program thereon, which, when executed by a processor, performs the following steps:
[0030] Obtain the node susceptance matrix of the component under test under the anticipated fault condition, determine the total active power flow increment of the component under test under the anticipated fault condition, and obtain the voltage phase angle increment corresponding to each bus in the component under test based on the node susceptance matrix and the total active power flow increment. For each branch in the component under test, determine the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. Obtain the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. Obtain the active power flow of the current branch based on the ground state power flow and the active power flow increment. Determine the weighting coefficient and power flow limit value of the current branch, and input the active power flow, weighting coefficient, and power flow limit value into a preset severity index calculation model to obtain the anticipated fault severity index when the current branch is disconnected.
[0031] Fifthly, this application also provides a computer program product. The computer program product includes a computer program that, when executed by a processor, performs the following steps:
[0032] Obtain the node susceptance matrix of the component under test under the anticipated fault condition, determine the total active power flow increment of the component under test under the anticipated fault condition, and obtain the voltage phase angle increment corresponding to each bus in the component under test based on the node susceptance matrix and the total active power flow increment. For each branch in the component under test, determine the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. Obtain the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. Obtain the active power flow of the current branch based on the ground state power flow and the active power flow increment. Determine the weighting coefficient and power flow limit value of the current branch, and input the active power flow, weighting coefficient, and power flow limit value into a preset severity index calculation model to obtain the anticipated fault severity index when the current branch is disconnected.
[0033] The aforementioned method, apparatus, computer equipment, storage medium, and computer program products for anticipating faults in power system components obtain the node susceptance matrix of the component under anticipation of a fault, determine the total active power flow increment of the component under anticipation of a fault, and obtain the voltage phase angle increment corresponding to each bus in the component under anticipation of a fault based on the node susceptance matrix and the total active power flow increment. For each branch in the component under anticipation of a fault, determine the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. Obtain the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. Obtain the active power flow of the current branch based on the ground state power flow and the active power flow increment. Determine the weighting coefficient and power flow limit value of the current branch, and input the active power flow, weighting coefficient, and power flow limit value into a preset severity index calculation model to obtain the anticipation fault severity index when the current branch is disconnected. Therefore, a fast anticipatory fault scanning method based on graph parallel computing and superposition principle is proposed, as well as a detailed anticipatory fault power flow calculation method that reuses the ground state power flow bus numbering results and parallel calls of subqueries from the graph database platform, thereby shortening the time of detailed power flow calculation and improving the efficiency of anticipatory fault scanning. Attached Figure Description
[0034] Figure 1 This is an application environment diagram of a contingency scanning method for power system components in one embodiment;
[0035] Figure 2 This is a flowchart illustrating a contingency scanning method applied to power system components in one embodiment;
[0036] Figure 3 In one embodiment A schematic diagram of a linear network model;
[0037] Figure 4 In one embodiment, the branch is disconnected. A schematic diagram illustrating the application of the superposition principle;
[0038] Figure 5 This is a flowchart illustrating a pre-fault scanning method applied to power system components in a specific embodiment.
[0039] Figure 6 This is a structural block diagram of a contingency scanning device applied to power system components in one embodiment;
[0040] Figure 7 This is an internal structural diagram of a computer device in one embodiment. Detailed Implementation
[0041] To make the objectives, technical solutions, and advantages of this application clearer, the following detailed description is provided in conjunction with the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are merely illustrative and not intended to limit the scope of this application.
[0042] The anticipatory fault scanning method for power system components provided in this application embodiment can be applied to, for example... Figure 1 The application environment shown depicts a scenario where the terminal communicates with the server via a network. The data storage system stores the data that the server needs to process. This data storage system can be integrated onto the server, or it can be hosted in the cloud or on other network servers.
[0043] Specifically, the anticipatory fault scanning method for power system components provided in this application embodiment can be executed by a server.
[0044] For example, the server obtains the node susceptance matrix of the component under test under the expected fault condition, determines the total active power flow increment of the component under test under the expected fault condition, and obtains the voltage phase angle increment corresponding to each bus in the component under test based on the node susceptance matrix and the total active power flow increment. For each branch in the component under test, the server determines the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. The server obtains the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. The server obtains the active power flow of the current branch based on the ground state power flow and the active power flow increment. The server determines the weighting coefficient and power flow limit value of the current branch, and inputs the active power flow, weighting coefficient, and power flow limit value into a preset severity index calculation model to obtain the expected fault severity index when the current branch is disconnected.
[0045] In such Figure 1In the application environment shown, the terminal can be, but is not limited to, various personal computers, laptops, smartphones, and tablets. The server can be implemented using a standalone server or a server cluster consisting of multiple servers.
[0046] In one embodiment, such as Figure 2 As shown, a method for anticipating faults in power system components is provided. Figure 1 Taking the server in the example, the following steps are included:
[0047] Step S201: Obtain the node susceptance matrix of the component under test under the expected fault condition, determine the total active power flow increment of the component under test under the expected fault condition, and obtain the voltage phase angle increment corresponding to each bus in the component under test based on the node susceptance matrix and the total active power flow increment.
[0048] The nodal susceptance matrix is a matrix that describes the relationship between conductance and susceptance between nodes in a power system.
[0049] The active power flow increment refers to the magnitude of the change in active power flow at other nodes in the power system when the generation or load at a certain node changes. It is usually represented by ΔP, which indicates the change in power flow caused by the change in node power.
[0050] Specifically, the server obtains the node susceptance matrix of the component under test under the expected fault condition, determines the total active power flow increment of the component under test under the expected fault condition, and obtains the voltage phase angle increment corresponding to each bus in the component under test based on the node susceptance matrix and the total active power flow increment.
[0051] Step S202: For each branch in the component to be tested, determine the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch.
[0052] Specifically, the server determines the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch in the component to be tested.
[0053] Step S203: Based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch, obtain the active power flow increment of the current branch.
[0054] Specifically, the server obtains the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch.
[0055] Step S204: Obtain the active power flow of the current branch based on the ground state power flow and active power flow increment of the current branch.
[0056] Active power flow refers to the transmission and distribution of active power in a power system along transmission lines. It describes the flow of active power between power source nodes and load nodes.
[0057] Specifically, the server obtains the active power flow of the current branch based on the ground-state power flow and the active power flow increment of the current branch.
[0058] For example, branch roads The power flow of each branch after the circuit is disconnected can be calculated using the following formula:
[0059]
[0060] In the above formula, branch road After the branch road is opened The meritorious trend, It is the ground state current. It is a positive force that increases the trend.
[0061] Step S205: Determine the weight coefficient and power flow limit value of the current branch, input the active power flow, weight coefficient and power flow limit value into the preset severity index calculation model, and obtain the expected fault severity index when the current branch is disconnected.
[0062] The preset severity index calculation model can be:
[0063]
[0064] In the above formula, branch road The weighting coefficients, For branch road collection, branch road Branch circuit under open condition The trend branch road The trend limit value.
[0065] Specifically, the server determines the weight coefficient and power flow limit value of the current branch, and inputs the active power flow, weight coefficient and power flow limit value into the preset severity index calculation model to obtain the expected fault severity index when the current branch is disconnected.
[0066] In the aforementioned method for anticipating faults in power system components, the node susceptance matrix of the component under test under anticipated fault conditions is obtained to determine the total active power flow increment of the component under test under anticipated fault conditions. Based on the node susceptance matrix and the total active power flow increment, the voltage phase angle increment corresponding to each bus in the component under test is obtained. For each branch in the component under test, the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch are determined. Based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch, the active power flow increment of the current branch is obtained. Based on the ground-state power flow and the active power flow increment of the current branch, the active power flow of the current branch is obtained. The weighting coefficient and power flow limit value of the current branch are determined. The active power flow, weighting coefficient, and power flow limit value are input into a preset severity index calculation model to obtain the anticipated fault severity index when the current branch is disconnected. Therefore, a fast anticipatory fault scanning method based on graph parallel computing and superposition principle is proposed, as well as a detailed anticipatory fault power flow calculation method that reuses the ground state power flow bus numbering results and parallel calls of subqueries from the graph database platform, thereby shortening the time of detailed power flow calculation and improving the efficiency of anticipatory fault scanning.
[0067] It should be noted that in the analysis of anticipated faults in power systems, the direct method is one of the commonly used fault scanning methods in order to improve the speed of fault scanning. That is, it quickly calculates the approximate power flow after a fault, usually using a DC power flow model. Its basic calculation formula is as follows:
[0068]
[0069] in, The node susceptance matrix of the currently running network. Let be the vector of voltage phase angles of each node in the network. The active power vector injected into the node.
[0070] The superposition principle can be applied to linear networks of power systems, and the above... The algorithm basically satisfies this condition. The following section specifically illustrates the graph-parallel computation process of the fast scan method based on the superposition principle, taking an open-circuit fault on a line in a power network as an example.
[0071] For example Figure 3 The network model shown has branches. When opening a circuit, it is equivalent to opening a busbar. and Add a susceptance between them Side roads, such as Figure 4 As shown in (a); branch The increase will make the busbar and The net injected power changes, and the change is the amount of power flowing through the new branch. The active power. Since the anticipated fault analysis always starts from a convergent ground-state power flow solution, therefore Figure 4 The network shown in (b) represents the ground-state power flow solution, which is known. According to the superposition principle, to find the open / closed branch... The subsequent network flow solutions can be obtained separately. Figure 4 (c) The network power flow solution and the ground state power flow solution are then superimposed together.
[0072] against Figure 4 The network in (c) has
[0073]
[0074] in, The nodal susceptance matrix after the fault. Let be the matrix of phase angle changes of the node voltage; according to the above formula, we first need to calculate... and Then the solution can be obtained. .
[0075] In one embodiment, step S201 above, obtaining the nodal susceptance matrix of the component under the anticipated fault condition, specifically includes the following steps:
[0076] Determine the initial matrix corresponding to the ground state power flow of the current branch; based on the initial matrix, obtain the matrix after the ground state power flow changes under the expected fault condition; use the matrix correction method to correct the changed matrix to obtain the nodal susceptance matrix of the component under test under the expected fault condition.
[0077] Ground-state power flow refers to the power flow distribution of a power system under steady-state operating conditions. It describes the direction and magnitude of power flow between power sources, loads, and transmission lines.
[0078] Specifically, the server determines the initial matrix corresponding to the ground state power flow of the current branch; based on the initial matrix, it obtains the matrix after the ground state power flow changes under the expected fault condition; using the matrix correction method, it corrects the changed matrix to obtain the nodal susceptance matrix of the component under test under the expected fault condition.
[0079] For example, the matrix correction method is used for rapid correction in anticipated fault analysis. One method for dealing with matrices. When the dimension of the electrical coefficient matrix is constant, a first-order correction technique can be used.
[0080] For the ground-state power flow, its matrix can be decomposed as follows:
[0081]
[0082] When the power grid structure or parameters change, the changed matrix can be represented as:
[0083]
[0084]
[0085] in, and They are respectively dimensional vector, For a scalar
[0086]
[0087]
[0088]
[0089]
[0090] Therefore, the correction formula can be written as:
[0091]
[0092]
[0093]
[0094]
[0095]
[0096]
[0097] That is, the corrected matrix can be calculated based on the previous decomposed matrix, and the added corrected matrix satisfies:
[0098]
[0099]
[0100]
[0101]
[0102] The subscript 1 here indicates the first fault. As you can see, for multiple faults, the above process can be repeated until the entire matrix decomposition process is completed.
[0103] In this embodiment, the nodal susceptance matrix of the component under test under the expected fault condition is obtained quickly and accurately by using the matrix correction method to correct the changed matrix.
[0104] In one embodiment, step S201 above, based on the nodal susceptance matrix and the total active power flow increment, obtains the voltage phase angle increment corresponding to each bus in the element under test, specifically including the following steps:
[0105] The node susceptance matrix and the total active power flow increment are input into a preset voltage phase angle increment matrix operation model to obtain the voltage phase angle increment matrix of the component under test under the expected fault condition; based on the voltage phase angle increment matrix, the voltage phase angle increment corresponding to each bus in the component under test is determined.
[0106] The preset voltage phase angle increment matrix operation model can be:
[0107]
[0108] In the above formula, The nodal susceptance matrix after the fault. This is the node voltage phase angle increment matrix. This contributes to the total increase in the tidal current.
[0109] Specifically, the server inputs the node susceptance matrix and the total active power flow increment into a preset voltage phase angle increment matrix operation model to obtain the voltage phase angle increment matrix of the component under test under the expected fault condition; based on the voltage phase angle increment matrix, the voltage phase angle increment corresponding to each bus in the component under test is determined.
[0110] In this embodiment, by using a preset voltage phase angle increment matrix operation model, the voltage phase angle increment matrix of the component under test under the expected fault condition is accurately obtained, thereby determining the voltage phase angle increment corresponding to each bus in the component under test.
[0111] In one embodiment, step S202 above, determining the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch, specifically includes the following steps:
[0112] Determine the first bus and the second bus corresponding to the current branch; take the voltage phase angle increment of the first bus as the first voltage phase angle increment, and take the voltage phase angle increment of the second bus as the second voltage phase angle increment; based on the first bus and the second bus, obtain the reactance value of the current branch.
[0113] In a power system, a busbar refers to a conductive rod or wire that connects multiple electrical devices or circuits together.
[0114] Specifically, the server determines the first bus and the second bus corresponding to the current branch; takes the voltage phase angle increment of the first bus as the first voltage phase angle increment, and takes the voltage phase angle increment of the second bus as the second voltage phase angle increment; and obtains the reactance value of the current branch based on the first bus and the second bus.
[0115] In this embodiment, by first determining the first busbar and the second busbar corresponding to the current branch, the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch are determined accordingly.
[0116] In one embodiment, step S203 above, based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch, obtains the active power flow increment of the current branch, specifically including the following steps:
[0117] Based on the first voltage phase angle increment and the second voltage phase angle increment, the voltage phase angle increment difference corresponding to the first voltage phase angle increment and the second voltage phase angle increment is obtained; the voltage phase angle increment difference and the reactance value of the current branch are input into the preset active power flow increment calculation model to obtain the active power flow increment of the current branch.
[0118] The preset active power flow increment calculation model can be:
[0119]
[0120] In the above formula, branch road The positive power flow increment; busbar The voltage phase angle increment; branch road The reactance.
[0121] Specifically, the server obtains the voltage phase angle increment difference corresponding to the first voltage phase angle increment and the second voltage phase angle increment based on the first voltage phase angle increment and the second voltage phase angle increment; inputs the voltage phase angle increment difference and the reactance value of the current branch into the preset active power flow increment calculation model to obtain the active power flow increment of the current branch.
[0122] In this embodiment, the active power flow increment of the current branch is accurately obtained by using a preset active power flow increment calculation model.
[0123] In one embodiment, step S201 above, determining the total active power flow increment of the component under the anticipated fault condition, specifically includes the following steps:
[0124] Obtain the vector of voltage phase angle of each node in the component under test; input the vector of voltage phase angle of each node in the component under test into the preset active power flow total increment calculation model to obtain the total active power flow increment.
[0125] The preset calculation model for the total active power flow increment can be:
[0126]
[0127] In the above formula, This is a vector of the voltage phase angles of each node in the element to be tested.
[0128] Specifically, the server obtains the vector of the voltage phase angle of each node in the component under test; the vector of the voltage phase angle of each node in the component under test is input into the preset active power flow total increment calculation model to obtain the total active power flow increment.
[0129] In this embodiment, the total active power flow increment corresponding to the element to be detected is accurately obtained by using a preset active power flow total increment calculation model.
[0130] In one embodiment, such as Figure 6 As shown, a method for anticipating faults in power system components is provided in a specific embodiment, which includes the following steps:
[0131] Step S501: Determine the initial matrix corresponding to the ground state power flow of the current branch; based on the initial matrix, obtain the matrix after the ground state power flow changes under the expected fault condition; use the matrix correction method to correct the changed matrix to obtain the node susceptance matrix of the component under test under the expected fault condition.
[0132] Step S502: Obtain the vector of voltage phase angle of each node in the component under test; input the vector of voltage phase angle of each node in the component under test into the preset active power flow increment calculation model to obtain the total active power flow increment of the component under test under the expected fault condition.
[0133] Step S503: Input the node susceptance matrix and the total active power flow increment into the preset voltage phase angle increment matrix operation model to obtain the voltage phase angle increment matrix of the component under test under the expected fault condition; based on the voltage phase angle increment matrix, determine the voltage phase angle increment corresponding to each bus in the component under test.
[0134] Step S504: For each branch in the component to be tested, determine the first bus and the second bus corresponding to the current branch; take the voltage phase angle increment of the first bus as the first voltage phase angle increment, and take the voltage phase angle increment of the second bus as the second voltage phase angle increment; based on the first bus and the second bus, obtain the reactance value of the current branch.
[0135] Step S505: Based on the first voltage phase angle increment and the second voltage phase angle increment, obtain the voltage phase angle increment difference corresponding to the first voltage phase angle increment and the second voltage phase angle increment; input the voltage phase angle increment difference and the reactance value into the preset active power flow increment calculation model to obtain the active power flow increment of the current branch.
[0136] Step S506: Obtain the active power flow of the current branch based on the ground state power flow and active power flow increment of the current branch.
[0137] Step S507: Determine the weight coefficient and power flow limit value of the current branch, input the active power flow, weight coefficient and power flow limit value into the preset severity index calculation model, and obtain the expected fault severity index when the current branch is disconnected.
[0138] The beneficial effects of the above embodiments are as follows:
[0139] This solution proposes a fast anticipatory fault scanning method based on graph parallel computing and overlay principles, as well as a detailed anticipatory fault power flow calculation method that reuses the base-state power flow bus numbering results and parallel calls to subqueries from the graph database platform. By combining these methods, the calculation time for fast anticipatory fault scanning is improved by 13 times, and the calculation time for 100 detailed power flows in a 10,000-bus system is less than 3 seconds. Specifically, for the 2749 bus system in the main network, the fast scanning calculation time for 2003 faults is less than 300 milliseconds, with an average calculation time of 0.15 milliseconds per fault; for the 8505 bus system in the main distribution network, the fast scanning calculation time for 2128 faults is less than 800 milliseconds, with an average calculation time of 0.375 milliseconds per fault. Compared to the current average fast scanning time of 2.09 milliseconds for a single fault in the main network (2749 buses), the calculation speed is improved by approximately 14 times.
[0140] For example, Tables 1 and 2 show the computational performance of the main network 2749 bus and the main distribution network 8505 bus system based on graph calculations, respectively.
[0141] Table 1. Results of rapid scan calculation for anticipated fault analysis of the 2749 bus system in the main network.
[0142]
[0143] Table 2. Results of Rapid Fault Scanning Calculation for the 8505 Busbar System of the Main and Distribution Network
[0144]
[0145] It should be understood that although the steps in the flowcharts of the embodiments described above are shown sequentially according to the arrows, these steps are not necessarily executed in the order indicated by the arrows. Unless explicitly stated herein, there is no strict order restriction on the execution of these steps, and they can be executed in other orders. Moreover, at least some steps in the flowcharts of the embodiments described above may include multiple steps or multiple stages. These steps or stages are not necessarily completed at the same time, but can be executed at different times. The execution order of these steps or stages is not necessarily sequential, but can be performed alternately or in turn with other steps or at least some of the steps or stages of other steps.
[0146] Based on the same inventive concept, this application also provides a device for anticipating faults in power system components to implement the aforementioned method for anticipating faults in power system components. The solution provided by this device is similar to the solution described in the above method. Therefore, the specific limitations of one or more embodiments of the device for anticipating faults in power system components provided below can be found in the limitations of the method for anticipating faults in power system components described above, and will not be repeated here.
[0147] In one embodiment, such as Figure 6 As shown, a predictive fault scanning device for power system components is provided, comprising:
[0148] The phase angle increment module 601 is used to obtain the node susceptance matrix of the component under test under the expected fault condition, determine the total active power flow increment of the component under test under the expected fault condition, and obtain the voltage phase angle increment corresponding to each bus in the component under test based on the node susceptance matrix and the total active power flow increment.
[0149] The reactance calculation module 602 is used to determine the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch for each branch in the component to be tested.
[0150] The power flow increment module 603 is used to obtain the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value.
[0151] The active power flow module 604 is used to obtain the active power flow of the current branch based on the ground state power flow and the active power flow increment of the current branch.
[0152] The index determination module 605 is used to determine the weight coefficient and power flow limit value of the current branch. The active power flow, weight coefficient and power flow limit value are input into the preset severity index calculation model to obtain the expected fault severity index when the current branch is disconnected.
[0153] In one embodiment, the phase angle increment module 601 is further used to determine the initial matrix corresponding to the ground state power flow of the current branch; based on the initial matrix, obtain the matrix after the ground state power flow changes under the expected fault condition; and use the matrix correction method to correct the changed matrix to obtain the node susceptance matrix of the element under test under the expected fault condition.
[0154] In one embodiment, the phase angle increment module 601 is further configured to input the node susceptance matrix and the total active power flow increment into a preset voltage phase angle increment matrix operation model to obtain the voltage phase angle increment matrix of the component under test under the expected fault condition; and determine the voltage phase angle increment corresponding to each bus in the component under test based on the voltage phase angle increment matrix.
[0155] In one embodiment, the reactance calculation module 602 is further configured to determine the first bus and the second bus corresponding to the current branch; use the voltage phase angle increment of the first bus as the first voltage phase angle increment, and the voltage phase angle increment of the second bus as the second voltage phase angle increment; and obtain the reactance value of the current branch based on the first bus and the second bus.
[0156] In one embodiment, the power flow increment module 603 is further configured to obtain the voltage phase angle increment difference corresponding to the first voltage phase angle increment and the second voltage phase angle increment based on the first voltage phase angle increment and the second voltage phase angle increment; input the voltage phase angle increment difference and the reactance value of the current branch into a preset active power flow increment calculation model to obtain the active power flow increment of the current branch.
[0157] In one embodiment, the phase angle increment module 601 is further configured to obtain the vector of the voltage phase angle of each node in the element to be detected; input the vector of the voltage phase angle of each node in the element to be detected into a preset active power flow total increment calculation model to obtain the active power flow total increment.
[0158] The modules in the aforementioned anticipatory fault scanning device applied to power system components can be implemented entirely or partially through software, hardware, or a combination thereof. These modules can be embedded in or independent of the processor in a computer device, or stored in the memory of a computer device as software, so that the processor can call and execute the corresponding operations of each module.
[0159] In one embodiment, a computer device is provided, which may be a server, and its internal structure diagram may be as follows: Figure 7As shown, this computer device includes a processor, memory, input / output (I / O) interfaces, and a communication interface. The processor, memory, and I / O interfaces are connected via a system bus, and the communication interface is also connected to the system bus via the I / O interfaces. The processor provides computational and control capabilities. The memory includes non-volatile storage media and internal memory. The non-volatile storage media stores the operating system, computer programs, and a database. The internal memory provides the environment for the operation of the operating system and computer programs stored in the non-volatile storage media. The I / O interfaces are used for exchanging information between the processor and external devices. The communication interface is used for communicating with external terminals via a network connection. When the computer program is executed by the processor, it implements a method for predicting faults in power system components.
[0160] Those skilled in the art will understand that Figure 7 The structure shown is merely a block diagram of a portion of the structure related to the present application and does not constitute a limitation on the computer device to which the present application is applied. Specific computer devices may include more or fewer components than those shown in the figure, or combine certain components, or have different component arrangements.
[0161] In one embodiment, a computer device is also provided, including a memory and a processor, wherein the memory stores a computer program, and the processor executes the computer program to implement the steps in the above method embodiments.
[0162] In one embodiment, a computer-readable storage medium is provided having a computer program stored thereon that, when executed by a processor, implements the steps in the above method embodiments.
[0163] In one embodiment, a computer program product is provided, including a computer program that, when executed by a processor, implements the steps in the above method embodiments.
[0164] It should be noted that the user information (including but not limited to user device information, user personal information, etc.) and data (including but not limited to data used for analysis, data stored, data displayed, etc.) involved in this application are all information and data authorized by the user or fully authorized by all parties, and the collection, use and processing of related data must comply with the relevant laws, regulations and standards of the relevant countries and regions.
[0165] Those skilled in the art will understand that all or part of the processes in the above embodiments can be implemented by a computer program instructing related hardware. The computer program can be stored in a non-volatile computer-readable storage medium. When executed, the computer program can include the processes of the embodiments described above. Any references to memory, databases, or other media used in the embodiments provided in this application can include at least one of non-volatile and volatile memory. Non-volatile memory can include read-only memory (ROM), magnetic tape, floppy disk, flash memory, optical memory, high-density embedded non-volatile memory, resistive random access memory (ReRAM), magnetic random access memory (MRAM), ferroelectric random access memory (FRAM), phase change memory (PCM), graphene memory, etc. Volatile memory can include random access memory (RAM) or external cache memory, etc. By way of illustration and not limitation, RAM can take many forms, such as Static Random Access Memory (SRAM) or Dynamic Random Access Memory (DRAM). The databases involved in the embodiments provided in this application may include at least one type of relational database and non-relational database. Non-relational databases may include, but are not limited to, blockchain-based distributed databases. The processors involved in the embodiments provided in this application may be general-purpose processors, central processing units, graphics processing units, digital signal processors, programmable logic devices, quantum computing-based data processing logic devices, etc., and are not limited to these.
[0166] The technical features of the above embodiments can be combined in any way. For the sake of brevity, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.
[0167] The embodiments described above are merely illustrative of several implementation methods of this application, and while the descriptions are specific and detailed, they should not be construed as limiting the scope of this patent application. It should be noted that those skilled in the art can make various modifications and improvements without departing from the concept of this application, and these all fall within the protection scope of this application. Therefore, the protection scope of this application should be determined by the appended claims.
Claims
1. A method for predicting faults in power system components, characterized in that, The method includes: Determine the initial matrix corresponding to the ground state power flow of the current branch; based on the initial matrix, obtain the matrix after the ground state power flow changes under the expected fault condition; use the matrix correction method to correct the changed matrix to obtain the node susceptance matrix of the component under test under the expected fault condition; determine the total active power flow increment of the component under test under the expected fault condition, and based on the node susceptance matrix and the total active power flow increment, obtain the voltage phase angle increment corresponding to each bus in the component under test; For each branch in the component to be tested, determine the first bus and the second bus corresponding to the current branch; take the voltage phase angle increment of the first bus as the first voltage phase angle increment, and take the voltage phase angle increment of the second bus as the second voltage phase angle increment; obtain the reactance value of the current branch based on the first bus and the second bus; the first bus and the second bus are conductors that connect multiple power devices or circuits together; The active power flow increment of the current branch is obtained based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch. The active power flow of the current branch is obtained based on the ground state power flow and the active power flow increment of the current branch. Determine the weighting coefficient and power flow limit value of the current branch, and input the active power flow, weighting coefficient and power flow limit value into a preset severity index calculation model to obtain the expected fault severity index when the current branch is disconnected.
2. The method according to claim 1, characterized in that, The step of obtaining the voltage phase angle increment corresponding to each bus in the element under test based on the node susceptance matrix and the total active power flow increment includes: The node susceptance matrix and the total active power flow increment are input into a preset voltage phase angle increment matrix calculation model to obtain the voltage phase angle increment matrix of the component under the expected fault condition. Based on the voltage phase angle increment matrix, the voltage phase angle increment corresponding to each bus in the element to be detected is determined.
3. The method according to claim 1, characterized in that, The step of obtaining the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value of the current branch includes: Based on the first voltage phase angle increment and the second voltage phase angle increment, the voltage phase angle increment difference corresponding to the first voltage phase angle increment and the second voltage phase angle increment is obtained; The voltage phase angle increment difference and the reactance value of the current branch are input into a preset active power flow increment calculation model to obtain the active power flow increment of the current branch.
4. The method according to any one of claims 1 to 3, characterized in that, Determining the total active power flow increment of the component under the anticipated fault condition includes: Obtain the vector of voltage phase angles of each node in the element to be detected; The vector of the voltage phase angle of each node in the element to be detected is input into a preset active power flow total increment calculation model to obtain the active power flow total increment.
5. A predictive fault scanning device for power system components, characterized in that, The device includes: The phase angle increment module is used to determine the initial matrix corresponding to the ground state power flow of the current branch; based on the initial matrix, the matrix after the ground state power flow changes under the expected fault condition is obtained; the matrix correction method is used to correct the changed matrix to obtain the node susceptance matrix of the component under test under the expected fault condition; the total active power flow increment of the component under test under the expected fault condition is determined; based on the node susceptance matrix and the total active power flow increment, the voltage phase angle increment corresponding to each bus in the component under test is obtained. The reactance calculation module is used to determine the first bus and the second bus corresponding to each branch in the component under test; to use the voltage phase angle increment of the first bus as the first voltage phase angle increment and the voltage phase angle increment of the second bus as the second voltage phase angle increment; and to obtain the reactance value of the current branch based on the first bus and the second bus; the first bus and the second bus are conductors that connect multiple power devices or circuits together; The power flow increment module is used to obtain the active power flow increment of the current branch based on the first voltage phase angle increment, the second voltage phase angle increment, and the reactance value. The active power flow module is used to obtain the active power flow of the current branch based on the ground state power flow and the active power flow increment of the current branch. The index determination module is used to determine the weight coefficient and power flow limit value of the current branch, and input the active power flow, weight coefficient and power flow limit value into a preset severity index calculation model to obtain the expected fault severity index when the current branch is disconnected.
6. A computer device comprising a memory and a processor, wherein the memory stores a computer program, characterized in that, When the processor executes the computer program, it implements the steps of the method according to any one of claims 1 to 4.
7. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by a processor, it implements the steps of the method according to any one of claims 1 to 4.
8. A computer program product, comprising a computer program, characterized in that, When the computer program is executed by a processor, it implements the steps of the method according to any one of claims 1 to 4.