Power distribution network voltage fluctuation management method, device, equipment, storage medium and program product

Abstract

This application relates to a method, apparatus, device, storage medium, and program product for managing voltage fluctuations in a distribution network. The method includes: determining the reactive power compensation capacity of each compensation node based on a pre-established objective function of the distribution network system; the objective function aims to minimize voltage fluctuations and distribution network losses, and the compensation nodes are nodes in the distribution network system equipped with static var generators (SVAs); determining the required reactive power injection for each node in the distribution network system according to a preset voltage-power mapping matrix; determining the target state variables of each SVA in the distribution network system based on the reactive power compensation capacity of each compensation node and the required reactive power injection for each node; and correcting the voltage of each compensation node in the distribution network system based on the target state variables of each SVA, thereby managing voltage fluctuations in the distribution network system. Global optimization through the objective function, combined with local node adjustment using state variables, improves control response efficiency.

Description

Technical Field

[0001] This application relates to the field of power distribution network technology, and in particular to a method, apparatus, equipment, storage medium, and program product for managing voltage fluctuations in power distribution networks. Background Technology

[0002] Currently, with the increasing prominence of energy issues and the vigorous development of clean energy, the scale of distributed generation in distribution networks is growing larger. Its inherent randomness and volatility cause frequent changes in power flow, leading to voltage fluctuations at distribution network nodes, sometimes exceeding safe operating limits and posing a serious challenge to the stable operation of the distribution network. Furthermore, the voltage fluctuations introduced by distributed generation exhibit complex diversity over time scales. On an hourly time scale, they are affected by periodic changes in sunlight intensity and intraday load curves; on a minute-scale time scale, they are affected by random events such as cloud cover, gusts, and instantaneous switching of large loads. Reactive power flow distribution is a key factor affecting voltage distribution. If reactive power flow distribution is unreasonable or lacks effective control, it will not only exacerbate the aforementioned voltage fluctuation problems but also increase system network losses. Sustained or severe voltage fluctuations can affect the normal operation and lifespan of electrical equipment, and in severe cases, even threaten the safe and stable operation of the distribution network. Therefore, how to optimize and control reactive power in the distribution network is one of the key technologies for effectively managing voltage fluctuation problems.

[0003] Traditional methods for managing voltage fluctuations in distribution networks employ a centralized control strategy. This involves a master station collecting information from the entire network and issuing unified control commands. Based on these commands, optimizations are performed from a global perspective to address voltage fluctuation issues.

[0004] However, the above methods suffer from control response lag. Summary of the Invention

[0005] Therefore, it is necessary to provide a method, apparatus, equipment, storage medium, and program product for effectively managing voltage fluctuations in distribution networks, addressing the aforementioned technical problems.

[0006] Firstly, this application provides a method for mitigating voltage fluctuations in a distribution network, comprising:

[0007] Based on the pre-established objective function of the distribution network system, the reactive power compensation capacity of each compensation node is determined; wherein, the objective function aims to minimize voltage fluctuations and distribution network losses, and the compensation node is a node in the distribution network system equipped with a static var generator;

[0008] The reactive power required to be injected into each node of the distribution network system is determined according to a preset voltage-power mapping matrix; the preset voltage-power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node of the distribution network system.

[0009] The target state variables of each static var generator in the power distribution network system are determined based on the reactive power compensation capacity of each compensation node and the reactive power to be injected into each node.

[0010] The voltage of each compensation node in the distribution network system is corrected based on the target state variables of each static var generator, so as to achieve the management of voltage fluctuations in the distribution network system.

[0011] In one embodiment, determining the target state variables of each static var generator in the distribution network system based on the reactive power compensation capacity of each of the compensation nodes and the reactive power to be injected by each node includes:

[0012] For each compensation node, the reactive power compensation capacity of the compensation node and the required reactive power to be injected are calculated to obtain the initial state variables of each static var generator.

[0013] The target state variables of each static var generator in the power distribution system are determined based on whether the initial state variables of each pair of adjacent static var generators are equal.

[0014] In one embodiment, determining the target state variable of each static var generator in the distribution network system based on whether the initial state variables of every two adjacent static var generators are equal includes:

[0015] For each pair of adjacent static var generators, if the initial state variables of the two static var generators are equal, the initial state variables of each static var generator shall be used as the target state variables of each static var generator.

[0016] If the initial state variables of the two static var generators are not equal, the initial state variables of each static var generator are adjusted until the adjusted state variables of all static var generators are equal, and the adjusted initial state variables are determined as the target state variables of the static var generators.

[0017] In one embodiment, the step of correcting the voltage of each compensation node in the distribution network system based on the target state variables of each of the static var generators to achieve voltage fluctuation control in the distribution network system includes:

[0018] The control parameters are calculated based on the target state variables of each static var generator and the voltage values ​​of the corresponding compensation nodes; the control parameters include the maximum compensation value of reactive power and the absorption start value;

[0019] The voltage of each compensation node in the distribution network system is corrected according to the control parameters to obtain the compensation capacity of the static var generator. The static var generator is then adjusted according to the compensation capacity to manage voltage fluctuations in the distribution network.

[0020] In one embodiment, determining the reactive power to be injected into each node of the distribution network system according to a preset voltage-power mapping matrix includes:

[0021] For each node in the power distribution network system, obtain the current voltage value of the node;

[0022] The voltage limit of the node is determined by comparing the current voltage value of the node with the upper voltage limit.

[0023] Determine the sensitivity coefficient associated with the node from the preset voltage power mapping matrix;

[0024] The reactive power required to be injected into the node is determined based on the sensitivity coefficient and the voltage over-limit.

[0025] In one embodiment, determining the reactive power compensation capacity of each compensation node based on a pre-established objective function of the distribution network system includes:

[0026] Obtain the initial compensation capacity of each compensation node in the multiple sets of the distribution network;

[0027] Voltage fluctuations and distribution network losses are determined based on multiple initial compensation capacities, and the determined voltage fluctuations and distribution network losses are substituted into the objective function for iterative calculation.

[0028] If the iteration termination conditions are met, the supplementary capacity at the end of the iteration is determined as the reactive power compensation capacity of each compensation node; wherein, the iteration termination conditions include minimum voltage fluctuation and minimum distribution network loss.

[0029] Secondly, this application also provides a device for mitigating voltage fluctuations in a distribution network, comprising:

[0030] The first determining module is used to determine the reactive power compensation capacity of each compensation node based on a pre-established objective function of the distribution network system; wherein the objective function aims to minimize voltage fluctuations and distribution network losses, and the compensation node is a node in the distribution network system equipped with a static var generator;

[0031] The calculation module is used to determine the reactive power to be injected into each node of the distribution network system according to a preset voltage-power mapping matrix; the preset voltage-power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node of the distribution network system.

[0032] The second determining module is used to determine the target state variables of each static var generator in the power distribution network system based on the reactive power compensation capacity of each compensation node and the reactive power to be injected by each node.

[0033] The correction module is used to correct the voltage of each compensation node in the distribution network system according to the target state variables of each static var generator, so as to achieve the management of voltage fluctuations in the distribution network system.

[0034] Thirdly, this application also provides a computer device, including a memory and a processor, wherein the memory stores a computer program, and the processor executes the computer program to perform the following steps:

[0035] Based on the pre-established objective function of the distribution network system, the reactive power compensation capacity of each compensation node is determined; wherein, the objective function aims to minimize voltage fluctuations and distribution network losses, and the compensation node is a node in the distribution network system equipped with a static var generator;

[0036] The reactive power required to be injected into each node of the distribution network system is determined according to a preset voltage-power mapping matrix; the preset voltage-power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node of the distribution network system.

[0037] The target state variables of each static var generator in the power distribution network system are determined based on the reactive power compensation capacity of each compensation node and the reactive power to be injected into each node.

[0038] The voltage of each compensation node in the distribution network system is corrected based on the target state variables of each static var generator, so as to achieve the management of voltage fluctuations in the distribution network system.

[0039] Fourthly, this application also provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, performs the following steps:

[0040] Based on the pre-established objective function of the distribution network system, the reactive power compensation capacity of each compensation node is determined; wherein, the objective function aims to minimize voltage fluctuations and distribution network losses, and the compensation node is a node in the distribution network system equipped with a static var generator;

[0041] The reactive power required to be injected into each node of the distribution network system is determined according to a preset voltage-power mapping matrix; the preset voltage-power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node of the distribution network system.

[0042] The target state variables of each static var generator in the power distribution network system are determined based on the reactive power compensation capacity of each compensation node and the reactive power to be injected into each node.

[0043] The voltage of each compensation node in the distribution network system is corrected based on the target state variables of each static var generator, so as to achieve the management of voltage fluctuations in the distribution network system.

[0044] Fifthly, this application also provides a computer program product, including a computer program that, when executed by a processor, performs the following steps:

[0045] Based on the pre-established objective function of the distribution network system, the reactive power compensation capacity of each compensation node is determined; wherein, the objective function aims to minimize voltage fluctuations and distribution network losses, and the compensation node is a node in the distribution network system equipped with a static var generator;

[0046] The reactive power required to be injected into each node of the distribution network system is determined according to a preset voltage-power mapping matrix; the preset voltage-power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node of the distribution network system.

[0047] The target state variables of each static var generator in the power distribution network system are determined based on the reactive power compensation capacity of each compensation node and the reactive power to be injected into each node.

[0048] The voltage of each compensation node in the distribution network system is corrected based on the target state variables of each static var generator, so as to achieve the management of voltage fluctuations in the distribution network system.

[0049] The aforementioned methods, devices, equipment, storage media, and program products for managing voltage fluctuations in distribution networks first determine the reactive power compensation capacity of each compensation node based on a pre-established objective function of the distribution network system. Then, based on a preset voltage-power mapping matrix, the required reactive power injection at each node in the distribution network system is determined. Next, the target state variables of each static var generator (SVA) in the distribution network system are determined based on the reactive power compensation capacity and the required reactive power injection at each node. Finally, the voltage at each compensation node in the distribution network system is corrected based on the target state variables of each SVA to manage voltage fluctuations in the distribution network system. The objective function aims to minimize voltage fluctuations and distribution network losses; the compensation node is a node in the distribution network system equipped with a SVA; and the preset voltage-power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node in the distribution network system. By setting an objective function, the reactive power compensation of the distribution network system is globally optimized. Then, based on the analytical expression of node voltage amplitude and reactive power, the required reactive power regulation capacity of each node in the distribution network is accurately calculated. This effectively reflects the sensitivity of voltage changes between nodes to reactive power, optimizing the reactive power distribution and voltage regulation of the distribution network. By determining the state variables through the reactive power compensation capacity and the required injected reactive power, the local operating characteristic parameters can be adjusted, achieving coordinated management of voltage fluctuations in the distribution network system. Compared with the traditional centralized control strategy for distribution network management, which suffers from control response lag, this application achieves global optimization of the distribution network through an objective function and realizes local regulation of compensation nodes through the calculation of target state variables, achieving coordinated management of the distribution network system and improving control response efficiency. Attached Figure Description

[0050] To more clearly illustrate the technical solutions in the embodiments of this application or related technologies, the drawings used in the description of the embodiments of this application or related technologies will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this application. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.

[0051] Figure 1 This is an application environment diagram of a method for mitigating voltage fluctuations in a distribution network, as illustrated in one embodiment.

[0052] Figure 2 This is a flowchart illustrating a method for mitigating voltage fluctuations in a distribution network in one embodiment.

[0053] Figure 3 This is a flowchart illustrating the process of determining a target state variable in one embodiment;

[0054] Figure 4 This is a flowchart illustrating the process of determining the target state variable in another embodiment;

[0055] Figure 5 This is a schematic diagram of the process of adjusting the static var generator according to the compensation capacity in one embodiment;

[0056] Figure 6 This is a flowchart illustrating the process of determining the reactive power to be injected into a node in one embodiment.

[0057] Figure 7 This is a flowchart illustrating the process of determining the reactive power compensation capacity of each compensation node in one embodiment.

[0058] Figure 8 This is a flowchart illustrating a method for mitigating voltage fluctuations in a distribution network, as described in another embodiment.

[0059] Figure 9 This is a schematic diagram illustrating the application of a power distribution network topology in one embodiment;

[0060] Figure 10 This is an application diagram illustrating a communication circuit failure in one embodiment;

[0061] Figure 11 This is an application diagram showing a comparison of voltage distribution before optimization, centralized control, and optimization in one embodiment;

[0062] Figure 12 This is a structural block diagram of a distribution network voltage fluctuation mitigation device in one embodiment;

[0063] Figure 13 This is an internal structural diagram of a computer device in one embodiment. Detailed Implementation

[0064] 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.

[0065] It should be noted that the terms "first," "second," etc., used in this application can be used to describe various elements, but these elements are not limited by these terms. These terms are only used to distinguish the first element from the second element. The terms "comprising" and "having," and any variations thereof, used in this application, are intended to cover non-exclusive inclusion. The term "multiple" used in this application refers to two or more. The term "and / or" used in this application refers to one of the embodiments, or any combination of multiple embodiments.

[0066] Currently, with the increasing prominence of energy issues and the vigorous development of clean energy, the scale of distributed generation in distribution networks is growing larger. Its inherent randomness and volatility cause frequent changes in power flow, leading to voltage fluctuations at distribution network nodes, sometimes exceeding safe operating limits and posing a serious challenge to the stable operation of the distribution network. Furthermore, the voltage fluctuations introduced by distributed generation exhibit complex diversity over time scales. On an hourly time scale, they are affected by periodic changes in sunlight intensity and intraday load curves; on a minute-scale time scale, they are affected by random events such as cloud cover, gusts, and instantaneous switching of large loads. Reactive power flow distribution is a key factor affecting voltage distribution. If reactive power flow distribution is unreasonable or lacks effective control, it will not only exacerbate the aforementioned voltage fluctuation problems but also increase system network losses. Sustained or severe voltage fluctuations can affect the normal operation and lifespan of electrical equipment, and in severe cases, even threaten the safe and stable operation of the distribution network. Therefore, how to optimize and control reactive power in the distribution network is one of the key technologies for effectively managing voltage fluctuation problems. Traditional methods for managing voltage fluctuations in distribution networks employ a centralized control strategy. This involves a master station collecting information from the entire network and issuing unified control commands. Based on these commands, optimizations are then performed from a global perspective to address voltage fluctuations. However, this approach suffers from several drawbacks. First, it heavily relies on high-speed, reliable communication networks, resulting in delayed control response, heavy computational burden, and susceptibility to single-point failures at the master station. Second, local control strategies rely solely on local information for rapid responses, eliminating the need for communication. However, the lack of information exchange and coordination between management devices can lead to conflicts between local optimization and overall objectives, resulting in limited effectiveness and resource utilization.

[0067] In view of the above-mentioned technical problems, this application provides a method for managing distribution network voltage fluctuations that can improve the control response of the distribution network. The following embodiments will specifically illustrate the method for managing distribution network voltage fluctuations.

[0068] The method for mitigating voltage fluctuations in distribution networks provided in this application can be applied to, for example... Figure 1The application environment shown is illustrated. The processing device 102 is wiredly connected to the distribution network system 104, which contains multiple nodes, such as distributed photovoltaic systems, substations, or user access equipment. Some or all nodes are equipped with static var generators (SVMs), enabling short-distance communication between nodes. Each node is also equipped with various sensors to collect operational status information, such as voltage, current, power, and losses. The processing device 102 acquires the data collected by the sensors and the data transmitted by the SVMs, performs further calculations on the acquired data, and ultimately compensates the SVMs based on the calculation results to manage voltage fluctuations in the distribution network system. The processing device 102 can be, but is not limited to, various personal computers, laptops, smartphones, tablets, IoT devices, and portable wearable devices. IoT devices can include smart speakers, smart TVs, smart air conditioners, smart vehicle devices, and projection equipment. Portable wearable devices can include smartwatches, smart bracelets, and head-mounted devices. Head-mounted devices can include virtual reality (VR) devices, augmented reality (AR) devices, smart glasses, etc.

[0069] In one exemplary embodiment, such as Figure 2 As shown, a method for mitigating voltage fluctuations in a power distribution network is provided. This embodiment illustrates the application of this method to processing equipment. In this embodiment, the method includes:

[0070] S201, based on the pre-established objective function of the distribution network system, determines the reactive power compensation capacity of each compensation node.

[0071] The objective function aims to minimize voltage fluctuations and distribution network losses. The distribution network system comprises multiple nodes, with compensation nodes being those equipped with static var generators (SVG) in the hereinafter referred to as SVG. There must be at least two compensation nodes in the distribution network. It should be noted that the final determined reactive power compensation capacity for each compensation node represents the optimal reactive power compensation capacity under the condition of minimum voltage fluctuations and distribution network losses.

[0072] In the embodiments of this application, the database stores a pre-established objective function for the distribution network system. This objective function aims to minimize voltage fluctuations and distribution network losses. It is obtained by weighting various objectives and introducing a penalty function for voltage exceeding limits. When it is necessary to address voltage fluctuation issues in the distribution network system, the active power loss and voltage fluctuation values ​​are first collected before reactive power compensation is performed. Then, the corresponding active power loss and voltage fluctuation values ​​are collected after reactive power compensation is performed. The pre-established objective function is then called from the database, and the data collected in both instances are substituted into the objective function to calculate the optimal reactive power compensation capacity for each compensation node in the distribution network system.

[0073] Alternatively, the objective function can be expressed by the following relations (1)-(3):

[0074] (1);

[0075] (2);

[0076] (3);

[0077] In the formula, f1 represents the sum of active power losses in the distribution network system after reactive power compensation; f loss f1 is the initial active power loss of the distribution network system; f2 is the voltage fluctuation after reactive power compensation in the distribution network system; ΔV is the initial voltage fluctuation of the distribution network system; f0 is the penalty function; U i Let be the voltage of the i-th node.

[0078] It should be noted that, in order to increase the algorithm's control over voltage, this invention selects U imax = (1 + 7%) * Voltage reference value; U imin = (1-7%) * voltage reference value; λ=10.

[0079] Optionally, when calculating the optimal reactive power compensation capacity of each compensation node in the distribution network system, preset constraints can be used to constrain the distribution network system to ensure that the stability and security of the distribution network system operation reach the optimal level. The preset constraints include equality constraints and inequality constraints. The equality constraints can be expressed by the following relationship (4):

[0080] (4);

[0081] In the formula, P Gi P represents the active power of the power source connected to node i; Li P represents the active power of the load connected to node i; PVi The active power of the distributed photovoltaic system connected to node i; Q GiQ represents the reactive power connected to the power source at node i; PVi The reactive power of the distributed photovoltaic system connected to node i; Q SVGi The reactive power connected to the reactive power compensation device SVG at node i; Q Li G represents the reactive power of the load connected at node i; ij and B ij The elements of the nodal admittance matrix are represented by the conductance and susceptance between nodes i and j, respectively; U il This is the node voltage limit value. If U i Greater than U imax When the voltage exceeds the limit, formula (2) generates a voltage over-limit penalty; if U i Less than U imax Greater than U imin There is no limit exceeded, at this time U il =U i If the formula (2) does not produce an over-limit penalty, then formula (2) will not produce an over-limit penalty.

[0082] Inequality constraints can be expressed by the following relation (5):

[0083] (5);

[0084] In the formula, P PVamax To compensate for the upper limit of active power of distributed photovoltaic power at node a; P PVamin To compensate for the lower limit of active power of distributed photovoltaic power at node a; Q PVamax Q represents the upper limit of reactive power of distributed photovoltaic power at point a; PVamin Q represents the lower limit of reactive power of distributed photovoltaic power at point a; PVamax Q represents the upper limit of reactive power compensation for SVG at point a; PVamin U is the lower limit of reactive power compensation for SVG at point a; kmax U represents the upper limit of the voltage amplitude at node k; kmin is the lower limit of the voltage amplitude at node k; n is the number of nodes in the distribution network.

[0085] S202, determine the reactive power to be injected into each node of the distribution network system according to the preset voltage-power mapping matrix.

[0086] The preset voltage-power mapping matrix includes the mapping relationship between voltage amplitude and reactive power of each node in the distribution network system, as well as the mapping relationship between voltage amplitude and active power, voltage phase and reactive power, and voltage phase and active power.

[0087] Optionally, the preset voltage-power mapping matrix can be an analytical expression obtained by inverse transformation of the Jacobian matrix based on the power flow calculation of the distribution network system, and can be represented by the following relation (6):

[0088] (6);

[0089] In the formula, ΔP is the column vector of injected active power changes at each node of the distribution network system, ΔP=[ΔP1ΔP2…ΔP N ] T ΔQ is the column vector of injected reactive power changes at each node of the distribution network system, ΔQ=[ΔQ1ΔQ2…ΔQ N ] T Δδ is the column vector of voltage phase changes at each node in the distribution network system, Δδ=[Δδ1Δδ2…Δδ] N ] T ΔU is the column vector of voltage amplitude changes at each node of the distribution network system, ΔU=[ΔU1ΔU2…ΔU…] N ] T S δP S δQ S UP and S UQ This is the sensitivity coefficient matrix of the relevant column vectors.

[0090] In the embodiments of this application, as shown in equation (6), the change in the voltage amplitude of a node is related to the changes in active and reactive power of all nodes. Reactive power change, as an important factor in reactive power compensation, requires close attention. Considering the impact of SVG output reactive power on the node voltage amplitude, the mapping relationship between voltage amplitude and reactive power can be obtained by extracting and combining the data related to this situation in equation (6), which can be expressed by the following relationship (7):

[0091] (7);

[0092] In the formula, ΔU is the column vector of voltage amplitude changes at each node of the distribution network system, ΔQ is the column vector of injected reactive power changes at each node of the distribution network system, and S... UQ This is a sensitivity coefficient matrix for changes in voltage amplitude and reactive power.

[0093] Optionally, after obtaining the mapping relationship between voltage amplitude and reactive power, the reactive power required to be injected at each node can be calculated based on the voltage amplitude change sensitivity coefficient in the relationship.

[0094] S203, determine the target state variables of each static var generator in the distribution network system based on the reactive power compensation capacity of each compensation node and the reactive power to be injected into each node.

[0095] Among them, the state variable can be the ratio of the adjustable reactive power of the static var generator to the maximum reactive power, and the target state variable can be the optimal state variable when the state variables are consistent.

[0096] In the embodiments of this application, the adjustable reactive power of the static var generator of each compensation node can be determined according to the reactive power compensation capacity of each compensation node, the maximum reactive power of each compensation node can be determined according to the reactive power to be injected by each node, and finally the state variables of each compensation node can be determined based on the adjustable reactive power and the maximum reactive power, and the state variables can be optimized to obtain the target state variables of each static var generator.

[0097] S204 corrects the voltage of each compensation node in the distribution network system according to the target state variables of each static var generator, so as to achieve the management of voltage fluctuations in the distribution network system.

[0098] In the embodiments of this application, after determining the target state variables of each static var generator, the maximum value of SVG reactive power compensation and the initial value of SVG reactive power absorption can be calculated based on the target state variables. The voltage of the compensation node can be corrected by the maximum value of SVG reactive power compensation and the initial value of SVG reactive power absorption, thereby achieving the management of voltage fluctuations in the distribution network.

[0099] The aforementioned method for mitigating voltage fluctuations in distribution networks first determines the reactive power compensation capacity of each compensation node based on a pre-established objective function of the distribution network system. Then, it determines the required reactive power injection at each node according to a preset voltage-power mapping matrix. Next, it determines the target state variables of each static var generator (SVA) in the distribution network system based on the reactive power compensation capacity and the required reactive power injection at each node. Finally, it corrects the voltage at each compensation node in the distribution network system based on the target state variables of each SVA, thereby mitigating voltage fluctuations in the distribution network system. The objective function aims to minimize voltage fluctuations and distribution network losses; the compensation nodes are nodes in the distribution network system equipped with SVAs; and the preset voltage-power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node in the distribution network system. By setting an objective function, the reactive power compensation of the distribution network system is globally optimized. Then, based on the analytical expression of node voltage amplitude and reactive power, the required reactive power regulation capacity of each node in the distribution network is accurately calculated. This effectively reflects the sensitivity of voltage changes between nodes to reactive power, optimizing the reactive power distribution and voltage regulation of the distribution network. By determining the state variables through the reactive power compensation capacity and the required injected reactive power, the local operating characteristic parameters can be adjusted, achieving coordinated management of voltage fluctuations in the distribution network system. Compared with the traditional centralized control strategy for distribution network management, which suffers from control response lag, this application achieves global optimization of the distribution network through an objective function and realizes local regulation of compensation nodes through the calculation of target state variables, achieving coordinated management of the distribution network system and improving control response efficiency.

[0100] In one exemplary embodiment, such as Figure 3 As shown, the target state variables of each static var generator in the distribution network system are determined based on the reactive power compensation capacity of each compensation node and the reactive power to be injected into each node, including:

[0101] S301, for each compensation node, calculate the reactive power compensation capacity of the compensation node and the required reactive power to be injected to obtain the initial state variables of each static var generator.

[0102] In the embodiments of this application, for each compensation node, the reactive power compensation capacity of the compensation node is used as the adjustable reactive power of the static var generator of the compensation node, and the required reactive power is used as the maximum reactive power of the static var generator of the compensation node. The initial state variables of the static var generator of the compensation node are obtained by dividing the reactive power compensation capacity of the compensation node by the required reactive power. The initial state variables are expressed by the following relationship (8):

[0103] (8);

[0104] In the formula, Q SVG _ N The reactive power compensation capacity of node N; u SVG ΔQ is the initial state variable of the static var generator. N The required reactive power to be injected into node N.

[0105] S302, determine the target state variables of each static var generator in the distribution network system based on whether the initial state variables of each two adjacent static var generators are equal.

[0106] In the embodiments of this application, to avoid control response lag, adjacent static var generators are used as communication units to ensure rapid information exchange and calculation over short distances. After determining the initial state variables of the static var generators of all compensation nodes, it is determined whether the initial state variables of each pair of adjacent static var generators are equal, and the target state variable of each static var generator is determined based on the judgment result.

[0107] Determining the target state variable by using initial state variables ensures the stability of the static var generator in the power distribution system during reactive power compensation.

[0108] In one exemplary embodiment, such as Figure 4 As shown, the target state variables of each static var generator in the distribution network system are determined based on whether the initial state variables of any two adjacent static var generators are equal, including:

[0109] S401, for each pair of adjacent static var generators, if the initial state variables of the two static var generators are equal, the initial state variables of each static var generator are taken as the target state variables of each static var generator.

[0110] In the embodiments of this application, when the initial state variables of the two static var generators are equal, it indicates that the distribution network system is operating relatively stably at the current moment, and the initial state variables will not affect the subsequent voltage fluctuation correction results. Therefore, the initial state variables of each static var generator are used as the target state variables of each static var generator and participate in the calculation process of the subsequent voltage fluctuation correction results.

[0111] S402, when the initial state variables of the two static var generators are not equal, adjust the initial state variables of each static var generator until the adjusted state variables of all static var generators are equal, and determine the adjusted initial state variables as the target state variables of the static var generators.

[0112] In the embodiments of this application, when the initial state variables of two static var generators are not equal, it indicates that the current distribution network system is not stable, and the initial state variables of the static var generators need to be converged to achieve a unified stable value. The initial state variables of each static var generator are adjusted. Optionally, for every two adjacent static var generators, the two generators communicate with each other and exchange their current initial state variables. When the two initial state variables are not equal, the average of the two initial state variables can be calculated, and the calculated average is used as the state variable of the two static var generators at the next moment. After the state variables of all static var generators at the next moment have been calculated, it is continued to determine whether the initial state variables of every two adjacent static var generators are equal. If they are not equal, the adjustment method is continued until the adjusted state variables of all static var generators are equal. The final adjusted initial state variable is then determined as the target state variable of the static var generator.

[0113] Optionally, the initial state variables of each static var generator (SVR) can be adjusted according to a consensus protocol. Specifically, for every two adjacent SVRs, they communicate with each other and exchange their current initial state variables. If the two initial state variables are not equal, the consensus protocol is used to calculate the state variable of each SVR at the next time step. After all SVRs have calculated their state variables for the next time step, the initial state variables of every two adjacent SVRs are checked for equality. If they are not equal, the adjustment process continues until the adjusted state variables of all SVRs are equal. The final adjusted initial state variable is then determined as the target state variable for the SVR. Under the condition of a connected communication topology, let... To compensate for the state variables of the static var generator of node i, the consensus protocol is represented by the following relation (9):

[0114] (9);

[0115] In the formula: x i (k) represents the state of the SVG at node i at time k; Let represent the state of the SVG at node i at time k+1. Let be the state of the SVG at time k, which is the neighboring node j of the SVG at node i; ε is a positive convergence coefficient used to control the convergence speed of the algorithm. When k is sufficiently large, for any vertex, we have .

[0116] The matrix representation of the consensus protocol iteration is expressed by the following relation (10):

[0117] (10);

[0118] In the formula, P is an n-order non-negative weight matrix, P=I-εL, and I is an M-order identity matrix.

[0119] The values ​​of each element in the Laplace matrix L are represented by the following relation (11):

[0120] (11);

[0121] In the formula, a ij This indicates whether there is a communication connection between node i and node j. If node i and node j communicate, then a ij =1, if there is no a ij =0.

[0122] By setting a consensus protocol to adjust the state information of adjacent SVGs, the state variables of all SVGs can be converged to a unified stable value, thereby improving the control response efficiency of the power distribution network system.

[0123] In one exemplary embodiment, such as Figure 5 As shown, the voltage of each compensation node in the distribution network system is corrected based on the target state variables of each static var generator to manage voltage fluctuations in the distribution network system, including:

[0124] S501 calculates the control parameters based on the target state variables of each static var generator and the voltage values ​​of the corresponding compensation nodes.

[0125] The control parameters include the maximum value of reactive power compensation and the initial value of absorption.

[0126] In the embodiments of this application, after obtaining the target state variables of each static var generator (SVG), the state variable information of all SVGs is made consistent, the real-time voltage of the compensation node is obtained, and the maximum compensation value and the absorption start value of reactive power are calculated based on the target state variables of the SVG and the real-time voltage of the compensation node. Optionally, the maximum compensation value and the absorption start value of reactive power are expressed by the following relationship (12):

[0127] (12);

[0128] In the formula, V aQ，i This represents the maximum reactive power compensation value; V tQ，i u is the initial value for reactive power absorption. SVG Let V be the target state variable of the static var generator at node i. i Let be the real-time voltage of node i.

[0129] S502 corrects the voltage of each compensation node in the distribution network system according to the control parameters to obtain the compensation capacity of the static var generator, and adjusts the static var generator according to the compensation capacity to achieve the control of voltage fluctuations in the distribution network.

[0130] In the embodiments of this application, the calculated control parameters and real-time voltage are substituted into a preset droop control calculation formula to calculate the compensation capacity of the static var generator. The parameters of the static var generator when performing reactive power compensation are set as the compensation capacity to achieve the management of voltage fluctuations in the distribution network. Optionally, the droop control calculation formula is expressed by the following relationship (13):

[0131] (13);

[0132] In the formula, V aQThis represents the maximum reactive power compensation value; V tQ V is the initial value for reactive power absorption. min V represents the minimum value at which a node can operate in a distribution network system. max V is the highest value that the node can operate at in the distribution network system, and V is the real-time voltage of the node.

[0133] In the above formula, the compensation node voltage value is lower than V. min SVG compensation capacity Q max (The maximum reactive power that the SVG can output); the voltage value of the compensation node is at V. min and V aQ Between these values, the SVG compensates for reactive power; when the voltage value of the compensation node is between V... aQ and V tQ When the voltage value of the compensation node is between V, no control is performed; tQ and V max Between these values, the SVG compensates for negative reactive power; the node voltage value connected to the photovoltaic system is higher than V. max SVG compensation-Q max .

[0134] In one exemplary embodiment, such as Figure 6 As shown, the reactive power to be injected into each node of the distribution network system is determined according to the preset voltage-power mapping matrix, including:

[0135] S601 obtains the current voltage value of each node in the distribution network system.

[0136] In embodiments of this application, the processing device can obtain the current voltage value from a sensor pre-configured on the node.

[0137] S602 determines the voltage limit of a node by comparing the node's current voltage value with its upper voltage limit.

[0138] In the embodiments of this application, the current voltage value of the node is subtracted from the upper voltage limit to calculate the voltage limit of the node. The upper voltage limit can be set according to the actual power consumption scenario, and is not limited here.

[0139] Alternatively, the voltage limit can be expressed by the following relationship (14):

[0140] (14);

[0141] In the formula, V max V is the upper limit of voltage. N Let ΔU be the current voltage value at node N. N The voltage limit of node N is the voltage amplitude in equation (7).

[0142] S603 determines the sensitivity coefficient associated with the node from the preset voltage power mapping matrix.

[0143] In the embodiments of this application, referring to equation (7), the sensitivity in the preset voltage power mapping matrix is ​​filtered to obtain the sensitivity coefficient associated with the node. For example, when the node is N, its associated sensitivity coefficient is: , i=1,2……N.

[0144] S604 determines the reactive power required to be injected into the node based on the sensitivity coefficient and voltage limit.

[0145] In the embodiments of this application, the sum of the voltage over-limit and the sensitivity coefficient is divided to obtain the reactive power to be injected into the node. Optionally, the reactive power to be injected into the node is expressed by the following relationship (15):

[0146] (15);

[0147] In the formula, Let ΔU be the sensitivity coefficient of node N. N For the voltage limit at node N, ΔQ N The reactive power required to be injected into node N.

[0148] In one exemplary embodiment, such as Figure 7 As shown, based on the pre-established objective function of the distribution network system, the reactive power compensation capacity of each compensation node is determined, including:

[0149] S701, obtain the initial compensation capacity of each compensation node in multiple distribution networks.

[0150] In the embodiments of this application, the initial compensation capacity of each compensation node in multiple distribution networks can be determined by random assignment method; alternatively, reactive power compensation data of each node used in multiple historical reactive power compensation cases in the web page interface can be obtained by web crawling technology, and multiple sets of reactive power compensation data can be used as the initial compensation capacity of each compensation node in the distribution network.

[0151] S702 determines voltage fluctuations and distribution network losses based on multiple initial compensation capacities, and substitutes the determined voltage fluctuations and distribution network losses into the objective function for iterative calculation.

[0152] In the embodiments of this application, an initial compensation capacity is extracted, the SVG of the distribution network system is initially configured, the voltage and loss values ​​of the distribution network before and after compensation are collected, and the collected parameters are substituted into equations (1)-(3) for calculation to obtain the first calculated value. The next initial compensation capacity is extracted, the SVG of the distribution network system is reconfigured, the voltage and loss values ​​of the distribution network before and after compensation are collected, and the collected parameters are substituted into equations (1)-(3) for calculation to obtain the second calculated value. The first calculated value and the second calculated value are compared, and the smallest calculated value is retained. A new initial compensation capacity is extracted, the SVG of the distribution network system is reconfigured, the voltage and loss values ​​of the distribution network before and after compensation are collected, and the collected parameters are substituted into equations (1)-(3) for calculation to obtain the third calculated value. The third calculated value is compared with the smallest retained calculated value, and the smallest calculated value is retained. The above steps are repeated to achieve iterative calculation.

[0153] S703, if the iteration termination condition is met, the supplementary capacity at the end of the iteration is determined as the reactive power compensation capacity of each compensation node.

[0154] The iteration termination conditions include minimizing voltage fluctuations and minimizing distribution network losses.

[0155] In the embodiments of this application, when the iteration reaches a preset iteration, or when the minimum calculated value has been determined based on multiple initial compensation capacities, indicating that the iteration ends, the supplementary capacity at the end of the iteration is determined as the reactive power compensation capacity of each compensation node.

[0156] In addition to the methods described in all the above embodiments, a method for mitigating voltage fluctuations in distribution networks is also provided, such as... Figure 8 As shown, the method includes:

[0157] S801, obtain the initial compensation capacity of each compensation node in multiple distribution networks; the compensation node is a node in the distribution network system that is equipped with a static var generator;

[0158] S802 determines voltage fluctuations and distribution network losses based on multiple initial compensation capacities, and substitutes the determined voltage fluctuations and distribution network losses into the objective function for iterative calculation; wherein, the objective function aims to minimize voltage fluctuations and distribution network losses;

[0159] S803, under the condition that the iteration ends, the supplementary capacity at the end of the iteration is determined as the reactive power compensation capacity of each compensation node; where the iteration ends condition includes the minimum voltage fluctuation and the minimum distribution network loss.

[0160] S804 obtains the current voltage value of each node in the distribution network system;

[0161] S805 determines the voltage limit of a node by comparing the node's current voltage value with its upper voltage limit.

[0162] S806, determine the sensitivity coefficient associated with the node from the preset voltage power mapping matrix; the preset voltage power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node in the distribution network system;

[0163] S807 determines the reactive power required to be injected into the node based on the sensitivity coefficient and voltage over-limit.

[0164] S808 calculates the reactive power compensation capacity and the required reactive power injection for each compensation node to obtain the initial state variables of each static var generator.

[0165] S809, for each pair of adjacent static var generators, if the initial state variables of the two static var generators are equal, the initial state variables of each static var generator are taken as the target state variables of each static var generator.

[0166] S810, when the initial state variables of the two static var generators are not equal, the initial state variables of each static var generator are adjusted until the adjusted state variables of all static var generators are equal, and the adjusted initial state variables are determined as the target state variables of the static var generators.

[0167] S811 calculates the control parameters based on the target state variables of each static var generator and the voltage values ​​of the corresponding compensation nodes; the control parameters include the maximum compensation value of reactive power and the absorption start value;

[0168] S812 corrects the voltage of each compensation node in the distribution network system according to the control parameters to obtain the compensation capacity of the static var generator, and adjusts the static var generator according to the compensation capacity to achieve the control of voltage fluctuations in the distribution network.

[0169] Each of the above steps has been described in the foregoing embodiments. For details, please refer to the foregoing content. They will not be repeated here.

[0170] The above embodiment will be explained using a typical distribution network connected to IEEE 33 nodes as an example. The topology of this distribution network is as follows: Figure 9 As shown, SVG is installed at nodes 8, 15 and 30 respectively. Before testing the governance strategy, the initial power flow calculation of the IEEE 33-node system is first performed. The results show that the total voltage fluctuation is 2.9055 pu and the total active power loss of the system is 0.8407 pu. The optimization objective function is obtained as follows (16), where the weight coefficient ω=0.3.

[0171] (16);

[0172] The voltage governance method based on multi-timescale collaborative optimization proposed in this invention adopts a hierarchical architecture. The short-timescale layer introduces a distributed consensus algorithm, establishing bidirectional communication connections between distributed SVGs to achieve information exchange with neighboring nodes. This bidirectional communication not only provides a reliable physical channel for information interaction between SVGs but also prevents network topology connectivity loss when a unidirectional communication line fails. Figure 10 For example, when a communication failure occurs between SVG1 and SVG2, relevant information about SVG2 and SVG1 can be indirectly obtained through multi-step data transmission between neighboring nodes SVG2 and SVG3 and other nodes, thereby ensuring the integrity and stability of the algorithm iteration process.

[0173] Table 1 Comparison of the effects of different control methods

[0174] Optimization plan Voltage fluctuation / pu Maximum node voltage / pu Minimum node voltage / pu Network loss / kW Consistency and Coordination 0.2417 1.0058 0.9596 1.3635 Centralized control 0.7252 0.9963 0.9636 0.8920

[0175] To verify the effectiveness of the method of this invention, it was compared with a centralized voltage control method. Table 1 lists the voltage fluctuation, node voltage, and network loss results under different methods. As can be seen from the table, the method of this invention is significantly effective in controlling voltage fluctuation: the voltage fluctuation is reduced from 2.9055 pu before optimization to 0.2417 pu, which is better than the 0.7252 pu of centralized control; the node voltage is maintained within the range of [0.9656, 1.00581] pu, which is more in line with the voltage requirements of the distribution network. At the same time, this method also shows good results in suppressing network losses. Figure 11 The figure shows a comparison of voltage distribution before optimization, under centralized control, and under the method of this invention. As can be seen from the figure, the method of this invention can significantly improve voltage fluctuations at multiple nodes and fully utilize the reactive power regulation capability of SVG, achieving rapid and stable voltage management without relying on a centralized control center.

[0176] It should be understood that although the steps in the flowcharts of the above embodiments 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 above embodiments 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 in other steps. It is understood that the steps in different embodiments can be freely combined as needed, and all non-contradictory solutions formed by such combinations are within the scope of protection of this application.

[0177] Based on the same inventive concept, this application also provides a distribution network voltage fluctuation mitigation device for implementing the above-described distribution network voltage fluctuation mitigation method. The solution provided by this device is similar to the implementation described in the above-described method. Therefore, the specific limitations in one or more distribution network voltage fluctuation mitigation device embodiments provided below can be found in the limitations of the distribution network voltage fluctuation mitigation method described above, and will not be repeated here.

[0178] In one exemplary embodiment, such as Figure 12 As shown, a device for mitigating voltage fluctuations in a power distribution network is provided, comprising: a first determining module 121, a calculation module 122, a second determining module 123, and a correction module 124, wherein:

[0179] The first determining module 121 is used to determine the reactive power compensation capacity of each compensation node based on the pre-established objective function of the distribution network system; wherein, the objective function aims to minimize voltage fluctuations and distribution network losses, and the compensation node is a node in the distribution network system equipped with a static var generator.

[0180] The calculation module 122 is used to determine the reactive power to be injected into each node of the distribution network system according to the preset voltage-power mapping matrix; the preset voltage-power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node of the distribution network system.

[0181] The second determining module 123 is used to determine the target state variables of each static var generator in the distribution network system based on the reactive power compensation capacity of each compensation node and the reactive power to be injected by each node.

[0182] The correction module 124 is used to correct the voltage of each compensation node in the distribution network system according to the target state variables of each static var generator, so as to achieve the management of voltage fluctuations in the distribution network system.

[0183] In an exemplary embodiment, the second determining module 123 described above includes:

[0184] The arithmetic unit is used to calculate the reactive power compensation capacity and the required reactive power to be injected for each compensation node, and to obtain the initial state variables of each static var generator.

[0185] The determination unit is used to determine the target state variables of each static var generator in the distribution network system based on whether the initial state variables of each two adjacent static var generators are equal.

[0186] In an exemplary embodiment, the determining unit includes:

[0187] The sub-unit is determined so that, for each pair of adjacent static var generators, if the initial state variables of the two static var generators are equal, the initial state variables of each static var generator are used as the target state variables of each static var generator.

[0188] The adjustment subunit is used to adjust the initial state variables of each static var generator when the initial state variables of the two static var generators are not equal, until the adjusted state variables of all static var generators are equal, and the adjusted initial state variables are determined as the target state variables of the static var generators.

[0189] In an exemplary embodiment, the above-mentioned correction module 124 includes:

[0190] The calculation unit is used to calculate the control parameters based on the target state variables of each static var generator and the voltage values ​​of the corresponding compensation nodes; the control parameters include the maximum compensation value of reactive power and the absorption start value;

[0191] The correction unit is used to correct the voltage of each compensation node in the distribution network system according to the control parameters, obtain the compensation capacity of the static var generator, and adjust the static var generator according to the compensation capacity to achieve the control of voltage fluctuations in the distribution network.

[0192] In an exemplary embodiment, the computing module 122 includes:

[0193] The first acquisition unit is used to acquire the current voltage value of each node in the distribution network system.

[0194] The first determining unit is used to determine the voltage limit of a node by comparing the node's current voltage value with its upper voltage limit.

[0195] The second determining unit is used to determine the sensitivity coefficient associated with the node from the preset voltage power mapping matrix;

[0196] The third determining unit is used to determine the reactive power required to be injected into the node based on the sensitivity coefficient and the voltage over-limit.

[0197] In an exemplary embodiment, the first determining module 121 described above includes:

[0198] The second acquisition unit is used to acquire the initial compensation capacity of each compensation node in multiple distribution networks;

[0199] The iterative unit is used to determine voltage fluctuations and distribution network losses based on multiple initial compensation capacities, and substitutes the determined voltage fluctuations and distribution network losses into the objective function for iterative calculation.

[0200] The fourth determining unit is used to determine the supplementary capacity at the end of the iteration as the reactive power compensation capacity of each compensation node when the iteration termination condition is met; wherein, the iteration termination condition includes the minimum voltage fluctuation and the minimum distribution network loss.

[0201] Each module in the aforementioned power distribution network voltage fluctuation mitigation device 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 computer device's memory as software, so that the processor can call and execute the corresponding operations of each module.

[0202] In one exemplary embodiment, a computer device is provided, which may be a server, and its internal structure diagram may be as follows: Figure 13 As 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 operating system and computer programs in the non-volatile storage media to run. The database stores voltage fluctuations, losses, and reactive power compensation amounts at nodes in the power distribution network system. The I / O interfaces are used for information exchange between the processor and external devices. The communication interface is used for communication with external terminals via a network connection. When the computer program is executed by the processor, it implements a method for managing voltage fluctuations in the power distribution network.

[0203] Those skilled in the art will understand that Figure 13 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.

[0204] In one exemplary embodiment, a computer device is 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-described method embodiments.

[0205] 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.

[0206] 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.

[0207] Those skilled in the art will understand that all or part of the processes in the methods of 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 of the above methods. Any references to memory, databases, or other media used in the embodiments provided in this application can include at least one of non-volatile memory 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, artificial intelligence (AI) processors, etc., and are not limited to these.

[0208] 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 application.

[0209] 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 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 mitigating voltage fluctuations in a power distribution network, characterized in that, The method includes: Based on the pre-established objective function of the distribution network system, the reactive power compensation capacity of each compensation node is determined; wherein, the objective function aims to minimize voltage fluctuations and distribution network losses, and the compensation node is a node in the distribution network system equipped with a static var generator; The reactive power required to be injected into each node of the distribution network system is determined according to a preset voltage-power mapping matrix; the preset voltage-power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node of the distribution network system. The target state variables of each static var generator in the power distribution network system are determined based on the reactive power compensation capacity of each compensation node and the reactive power to be injected into each node. The voltage of each compensation node in the distribution network system is corrected based on the target state variables of each static var generator, so as to achieve the management of voltage fluctuations in the distribution network system.

2. The method according to claim 1, characterized in that, The step of determining the target state variables of each static var generator in the distribution network system based on the reactive power compensation capacity of each compensation node and the reactive power to be injected by each node includes: For each compensation node, the reactive power compensation capacity of the compensation node and the required reactive power to be injected are calculated to obtain the initial state variables of each static var generator. The target state variables of each static var generator in the power distribution system are determined based on whether the initial state variables of each pair of adjacent static var generators are equal.

3. The method according to claim 2, characterized in that, The step of determining the target state variables of each static var generator in the distribution network system based on whether the initial state variables of every two adjacent static var generators are equal includes: For each pair of adjacent static var generators, if the initial state variables of the two static var generators are equal, the initial state variables of each static var generator shall be used as the target state variables of each static var generator. If the initial state variables of the two static var generators are not equal, the initial state variables of each static var generator are adjusted until the adjusted state variables of all static var generators are equal, and the adjusted initial state variables are determined as the target state variables of the static var generators.

4. The method according to claim 1, characterized in that, The step of correcting the voltage of each compensation node in the distribution network system based on the target state variables of each of the static var generators, in order to manage voltage fluctuations in the distribution network system, includes: The control parameters are calculated based on the target state variables of each static var generator and the voltage values ​​of the corresponding compensation nodes; the control parameters include the maximum compensation value of reactive power and the absorption start value; The voltage of each compensation node in the distribution network system is corrected according to the control parameters to obtain the compensation capacity of the static var generator. The static var generator is then adjusted according to the compensation capacity to manage voltage fluctuations in the distribution network.

5. The method according to claim 1, characterized in that, The step of determining the reactive power to be injected into each node of the distribution network system according to the preset voltage-power mapping matrix includes: For each node in the power distribution network system, obtain the current voltage value of the node; The voltage limit of the node is determined by comparing the current voltage value of the node with the upper voltage limit. Determine the sensitivity coefficient associated with the node from the preset voltage power mapping matrix; The reactive power required to be injected into the node is determined based on the sensitivity coefficient and the voltage over-limit.

6. The method according to claim 1, characterized in that, The determination of reactive power compensation capacity for each compensation node based on a pre-established objective function of the distribution network system includes: Obtain the initial compensation capacity of each compensation node in the multiple sets of the distribution network; Voltage fluctuations and distribution network losses are determined based on multiple initial compensation capacities, and the determined voltage fluctuations and distribution network losses are substituted into the objective function for iterative calculation. If the iteration termination conditions are met, the supplementary capacity at the end of the iteration is determined as the reactive power compensation capacity of each compensation node; wherein, the iteration termination conditions include minimum voltage fluctuation and minimum distribution network loss.

7. A device for mitigating voltage fluctuations in a power distribution network, characterized in that, The device includes: The first determining module is used to determine the reactive power compensation capacity of each compensation node based on a pre-established objective function of the distribution network system; wherein, the objective function aims to minimize voltage fluctuations and distribution network losses, and the compensation node is a node in the distribution network system equipped with a static var generator; The calculation module is used to determine the reactive power to be injected into each node of the distribution network system according to a preset voltage-power mapping matrix; the preset voltage-power mapping matrix includes the mapping relationship between the voltage amplitude and reactive power of each node of the distribution network system. The second determining module is used to determine the target state variables of each static var generator in the power distribution network system based on the reactive power compensation capacity of each compensation node and the reactive power to be injected by each node. The correction module is used to correct the voltage of each compensation node in the distribution network system according to the target state variables of each static var generator, so as to achieve the management of voltage fluctuations in the distribution network system.

8. 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 6.

9. 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 6.

10. 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 6.

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