An asynchronous power grid dispatching method, system, equipment, and medium for transmission and distribution coordination.

Abstract

This invention discloses an asynchronous power grid dispatching method, system, device, and medium for transmission and distribution coordination, relating to the field of power grid management technology. In the current iteration process, when first update data is received from at least S distribution systems, a forward-backward operator splitting algorithm is used to calculate second update data. Based on the second update data, the power flow value is calculated, and it is determined whether the power flow value meets the iteration termination condition. If not, the second update data is sent to the distribution system so that the distribution system issues first update data for the next iteration; if yes, dispatching data is obtained based on the power flow value, and power grid dispatching is performed. By employing this embodiment of the invention, the asynchronous forward-backward operator splitting algorithm is used to handle the problems of the transmission system and the distribution system separately, which can significantly improve the overall computational efficiency and operational stability of the integrated transmission and distribution system.

Description

Technical Field

[0001] This invention relates to the field of power grid management technology, and in particular to an asynchronous power grid dispatching method, system, equipment and medium for transmission and distribution coordination. Background Technology

[0002] In traditional power systems, transmission and distribution networks are often dispatched and controlled independently. While this hierarchical management system was able to meet the basic needs of the power system in the past, with the development of the electricity market and the construction of the energy internet, the coupling relationship between transmission and distribution networks has become increasingly complex.

[0003] Traditional methods for synchronously calculating power flow in the power grid are based on independent calculations of the transmission and distribution networks in traditional power systems. However, when applied to integrated transmission and distribution systems, they suffer from low computational efficiency and poor real-time performance, making it difficult for the computational efficiency and accuracy of the respective management systems of the transmission and distribution networks to meet engineering requirements. Summary of the Invention

[0004] The technical problem to be solved by this invention is how to improve the real-time performance of power grid dispatching, and to provide an asynchronous power grid dispatching method, system, equipment and medium for transmission and distribution coordination, which can significantly improve the computational efficiency and operational stability of the overall dispatching of the integrated transmission and distribution system.

[0005] To address the above technical problems, embodiments of the present invention provide an asynchronous power grid dispatching method with transmission and distribution coordination, comprising:

[0006] In the current iteration, when the first update data is received from at least S power distribution systems, the forward-backward operator splitting algorithm is used to calculate the second update data; both the first update data and the second update data include the boundary node data between the power transmission system and the power distribution system;

[0007] Based on the second updated data, the power flow value is calculated, and it is determined whether the power flow value meets the iteration termination condition.

[0008] If not, the second update data is sent to the power distribution system so that the power distribution system issues first update data for the next iteration based on the second update data.

[0009] If so, then scheduling data is obtained based on the power flow value, and power grid scheduling is performed based on the scheduling data.

[0010] As an improvement to the above scheme, in the current iteration process, when receiving first update data from at least S power distribution systems, the second update data is calculated using a forward-backward operator splitting algorithm, including:

[0011] During the current iteration, when first update data is received from at least S power distribution systems, the second update data from the previous iteration is obtained;

[0012] Based on the first updated data and the second updated data in the previous iteration, the first updated data is updated using the forward-backward operator splitting algorithm to obtain the second updated data for the current iteration.

[0013] As an improvement to the above scheme, if the current iteration is the first iteration, the step of obtaining the second update data from the previous iteration when receiving first update data from at least S power distribution systems during the current iteration includes:

[0014] Obtain initial boundary node data;

[0015] In the current iteration, when the first update data is received from at least S power distribution systems, the initial boundary node data is used as the second update data in the previous iteration.

[0016] As an improvement to the above scheme, the step of updating the first update data using a forward-backward operator splitting algorithm based on the first update data and the second update data in the previous iteration to obtain the second update data for the current iteration includes:

[0017] Based on the first updated data and the second updated data in the previous iteration, calculate the current global vector of the boundary node between the power transmission system and the power distribution system;

[0018] Calculate the power flow value of the transmission system based on the current global vector;

[0019] Based on the power flow value, the forward-backward operator splitting algorithm is used to update the current global vector to obtain the updated global variable;

[0020] Based on the updated global variable, the second updated data for the current iteration is obtained.

[0021] As an improvement to the above scheme, before calculating the second update data using the forward-backward operator splitting algorithm when receiving first update data from at least S distribution systems during the current iteration, the grid dispatch-based method further includes:

[0022] Obtain the lag step count for each of the power distribution systems; the lag step count for each of the power distribution systems is updated after each iteration;

[0023] The power distribution system with a lag step number of not less than τ is defined as a lag power distribution system;

[0024] Therefore, the at least S power distribution systems include lagging power distribution systems.

[0025] As an improvement to the above scheme, the method for updating the lag step count of each of the aforementioned power distribution systems includes:

[0026] If the first update data received during the current iteration comes from a power distribution system, then the lag step count of that power distribution system is reset after the current iteration.

[0027] If the first update data received in the current iteration does not come from a power distribution system, then the lag step number of the power distribution system is incremented after the current iteration.

[0028] As an improvement to the above scheme, the step of calculating the power flow value based on the second updated data and determining whether the power flow value meets the iteration termination condition includes:

[0029] The power flow value is calculated based on the second updated data; the power flow value includes the first power flow value of the transmission system and the second power flow value of each of the distribution systems.

[0030] Determine the convergence of the power flow values ​​of the power grid;

[0031] If the power flow value does not converge, it is considered that the power flow value does not meet the iteration termination condition;

[0032] If the power flow value converges, it is considered that the power flow value satisfies the iteration termination condition.

[0033] As an improvement to the above scheme, the step of calculating the power flow value based on the second updated data includes:

[0034] The voltage amplitude, voltage phase angle, active power, and reactive power of the boundary node between the power transmission system and the power distribution system are obtained based on the second updated data.

[0035] Calculate the first power flow value of the transmission system based on the voltage amplitude and the voltage phase angle;

[0036] Calculate the second power flow value for each of the power distribution systems based on the active power and the reactive power;

[0037] The power grid power flow value is obtained based on the first power flow value and the second power flow value.

[0038] As an improvement to the above scheme, determining the convergence of the power flow value includes:

[0039] The spectral radius index is calculated based on the power flow value of the power grid.

[0040] When the spectral radius index is less than 1, the power flow value is determined to be converged; otherwise, the power flow value is determined to be non-converged.

[0041] This invention also provides an asynchronous power grid dispatching system for transmission and distribution coordination, comprising:

[0042] The data update module is used to calculate the second update data using a forward-backward operator splitting algorithm when receiving the first update data from at least S power distribution systems during the current iteration; both the first update data and the second update data include the boundary node data between the power transmission system and the power distribution system;

[0043] The iteration end judgment module is used to calculate the power flow value based on the second updated data and determine whether the power flow value meets the iteration end condition.

[0044] The data sending module is configured to send the second update data to the power distribution system if not, so that the power distribution system can issue first update data for the next iteration based on the second update data.

[0045] The power grid dispatching module is used to obtain dispatching data based on the power grid flow value if the condition is met, and to perform power grid dispatching based on the dispatching data.

[0046] As an improvement to the above solution, the data update module includes:

[0047] The previous iteration data acquisition unit is used to acquire the second update data in the previous iteration when it receives the first update data from at least S power distribution systems;

[0048] The current iteration data update unit is used to update the first update data according to the first update data and the second update data in the previous iteration, using a forward-backward operator splitting algorithm to obtain the second update data for the current iteration.

[0049] As an improvement to the above scheme, if the current iteration is the first iteration, the previous iteration data acquisition unit is specifically used for:

[0050] Obtain initial boundary node data;

[0051] When the first update data is received from at least S power distribution systems, the initial boundary node data is used as the second update data in the previous iteration.

[0052] As an improvement to the above scheme, the current iteration data update unit is specifically used for:

[0053] Based on the first updated data and the second updated data in the previous iteration, calculate the current global vector of the boundary node between the power transmission system and the power distribution system;

[0054] Calculate the power flow value of the transmission system based on the current global vector;

[0055] Based on the power flow value, the forward-backward operator splitting algorithm is used to update the current global vector to obtain the updated global variable;

[0056] Based on the updated global variable, the second updated data for the current iteration is obtained.

[0057] As an improvement to the above scheme, the power grid dispatching system further includes:

[0058] The lag step acquisition module is used to acquire the lag step count of each of the power distribution systems; the lag step count of each of the power distribution systems is updated after each iteration;

[0059] A power distribution system screening module is used to identify power distribution systems with a lag step number of not less than τ as lag power distribution systems.

[0060] Therefore, the at least S power distribution systems include lagging power distribution systems.

[0061] As an improvement to the above scheme, the method for updating the lag step count of each of the aforementioned power distribution systems includes:

[0062] If the first update data received during the current iteration comes from a power distribution system, then the lag step count of that power distribution system is reset after the current iteration.

[0063] If the first update data received in the current iteration does not come from a power distribution system, then the lag step number of the power distribution system is incremented after the current iteration.

[0064] As an improvement to the above scheme, the iteration end judgment module includes:

[0065] A power flow calculation unit is used to calculate a power flow value based on the second updated data; the power flow value includes a first power flow value of the transmission system and a second power flow value of each of the distribution systems.

[0066] A convergence determination unit is used to determine the convergence of the power flow value of the power grid.

[0067] The first convergence determination unit is used to determine that if the power grid power flow value does not converge, the power grid power flow value does not meet the iteration termination condition.

[0068] The second convergence determination unit is used to determine if the power grid power flow value converges, and then consider that the power grid power flow value meets the iteration termination condition.

[0069] As an improvement to the above scheme, the power flow value calculation unit is specifically used for:

[0070] The voltage amplitude, voltage phase angle, active power, and reactive power of the boundary node between the power transmission system and the power distribution system are obtained based on the second updated data.

[0071] Calculate the first power flow value of the transmission system based on the voltage amplitude and the voltage phase angle;

[0072] Calculate the second power flow value for each of the power distribution systems based on the active power and the reactive power;

[0073] The power grid power flow value is obtained based on the first power flow value and the second power flow value.

[0074] As an improvement to the above scheme, the convergence determination unit is specifically used for:

[0075] The spectral radius index is calculated based on the power flow value of the power grid.

[0076] When the spectral radius index is less than 1, the power flow value is determined to be converged; otherwise, the power flow value is determined to be non-converged.

[0077] This invention also provides an asynchronous power grid dispatching device for transmission and distribution coordination, including a processor, a memory, and a computer program stored in the memory and configured to be executed by the processor. When the processor executes the computer program, it implements an asynchronous power grid dispatching method for transmission and distribution coordination as described above.

[0078] Compared with existing technologies, this invention discloses a power grid dispatching method, system, device, and medium. During the current iteration process, when first update data is received from at least S distribution systems, a forward-backward operator splitting algorithm is used to calculate second update data. Both the first and second update data include boundary node data between the transmission system and the distribution system. Based on the second update data, a power flow value is calculated, and it is determined whether the power flow value meets the iteration termination condition. If not, the second update data is sent to the distribution system, so that the distribution system issues first update data for the next iteration based on the second update data. If yes, dispatching data is obtained based on the power flow value, and power grid dispatching is performed based on the dispatching data. Using this embodiment of the invention can significantly improve the computational efficiency and operational stability of the overall dispatching of the integrated transmission and distribution system. Attached Figure Description

[0079] Figure 1 This is a flowchart illustrating the steps of an asynchronous power grid dispatching method for transmission and distribution coordination provided in an embodiment of the present invention.

[0080] Figure 2 This is a schematic diagram of a maximum hysteresis constraint provided by an embodiment of the present invention;

[0081] Figure 3 This is a timing diagram illustrating information interaction between a power transmission system and a power distribution system, provided in an embodiment of the present invention.

[0082] Figure 4 This is a schematic diagram of the structure of an asynchronous power grid dispatching system for transmission and distribution coordination provided in an embodiment of the present invention. Detailed Implementation

[0083] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0084] In the description and claims, it should be understood that the terms "first," "second," etc., used in the description and claims are only for the purpose of distinguishing the description of the same technical features, and should not be construed as indicating or implying relative importance or implicitly specifying the number of technical features indicated, nor necessarily the order of description or chronological order. The terms are interchangeable where appropriate. Therefore, a feature defined as "first" or "second" may explicitly or implicitly include at least one of that feature.

[0085] In traditional power systems, transmission and distribution networks are often dispatched and controlled independently. While this hierarchical management system met the basic needs of the power system in the past, its limitations have become increasingly apparent with the development of the electricity market and the construction of the energy internet. In integrated transmission and distribution systems, if traditional grid dispatching methods are still used, the computational efficiency and power consumption of the separate management systems for the transmission and distribution networks will be insufficient to meet engineering requirements.

[0086] It should be noted that, in this embodiment of the invention, it is more often applied to integrated power grids of transmission and distribution, wherein the power grid includes a transmission system and a distribution system, and the transmission system and the distribution system exchange information through boundary nodes to coordinate and correct their respective parameters.

[0087] It should also be noted that, due to the structure of power supply and consumption, one transmission system in the power grid generally corresponds to several distribution systems.

[0088] In traditional power grid dispatching methods, the transmission system updates the data at the boundary nodes after receiving data from all the distribution systems, and then sends the updated data back to the distribution systems, continuing the iteration until convergence.

[0089] However, traditional power grid dispatching methods require waiting for all distribution systems to complete data transmission. If there is a communication delay in the distribution system, each iteration will take a lot of time, resulting in low computational efficiency.

[0090] Based on the above considerations, embodiments of the present invention provide a power grid dispatching method applied to a power transmission system. Please refer to... Figure 1 In this embodiment, the power grid dispatching method is specifically executed through steps S1 to S4:

[0091] S1. In the current iteration, when the first update data is received from at least S power distribution systems, the forward-backward operator splitting algorithm is used to calculate the second update data; both the first update data and the second update data include the boundary node data between the power transmission system and the power distribution system.

[0092] It should be noted that in this embodiment of the invention, S is the minimum number of synchronizations. The power transmission system does not need to wait for all the data of the distribution system to be transmitted before performing calculations, as in the traditional scheduling method. When the power transmission network receives a sufficient number of first update data, it can start data updates and iterative calculations. This can alleviate the lag problem caused by communication delays or excessive computing load in some distribution systems and improve the overall computing efficiency of the system.

[0093] S2. Calculate the power flow value based on the second updated data, and determine whether the power flow value meets the iteration termination condition.

[0094] It should be noted that boundary nodes are the hubs between the transmission and distribution systems. By exchanging data at boundary nodes, the transmission and distribution systems can further solve the transmission and distribution problems, iteratively generating the optimal scheduling data scheme. During the iteration process, the distribution system sends first updated data to the transmission system. Based on the first updated data and the solution to the transmission sub-problem, the transmission system updates the boundary node data in the first updated data, and then sends the resulting second updated data to the distribution system. The distribution system, based on the second updated data and the solution to the distribution sub-problem, updates the boundary node data in the second updated data, obtaining the first updated data. This process is repeated continuously, ensuring that the final generated scheduling data tends towards the optimal solution for grid scheduling, guaranteeing the correctness and reliability of the scheduling data.

[0095] S3. If not, the second update data is sent to the power distribution system so that the power distribution system issues first update data for the next iteration based on the second update data.

[0096] S4. If so, then obtain the scheduling data based on the power flow value, and perform power grid scheduling based on the scheduling data.

[0097] It should also be noted that the power grid scheduling method employed in this embodiment of the invention is an asynchronous forward-backward operator splitting method. This asynchronous computation mode reduces the frequency of data exchange between computing nodes, improving computational efficiency and real-time performance. Specifically, the forward operator handles the computational tasks of the transmission system, while the backward operator handles the computational tasks of the distribution system. The two coordinate through information exchange at boundary nodes, gradually correcting their respective computational results until convergence is achieved. This method not only improves computational efficiency but also addresses, to some extent, the poor convergence problem present in traditional methods.

[0098] In this embodiment of the invention, by decomposing the computational tasks of the power transmission system and the power distribution system, and using the asynchronous forward-backward operator splitting algorithm to handle the problems of the power transmission system and the power distribution system respectively, the overall computational efficiency and operational stability of the integrated power transmission and distribution system can be significantly improved.

[0099] As a preferred implementation, step S1, during the current iteration, when first update data is received from at least S power distribution systems, the second update data is calculated using a forward-backward operator splitting algorithm, including:

[0100] During the current iteration, when first update data is received from at least S power distribution systems, the second update data from the previous iteration is obtained;

[0101] Based on the first updated data and the second updated data in the previous iteration, the first updated data is updated using the forward-backward operator splitting algorithm to obtain the second updated data for the current iteration.

[0102] It should be noted that the power flow value of a transmission system can be expressed as T. φ ([V B ;θ B ])=[P′ B ;Q′ B The power flow value of a power distribution system can be expressed as D. φ ([P B Q B ])=[V′ B ;θ′ B ]; where P′ B Q′ represents the active power of the boundary nodes in the first updated data.B V′ represents the reactive power of the boundary nodes in the first updated data. B The voltage magnitude of the boundary node in the second updated data; θ′ B This refers to the voltage phase angle of the boundary node in the second updated data. Therefore, the final active power of the boundary node is... reactive power voltage amplitude and voltage phase angle Must meet simultaneously and

[0103] It should also be noted that the first updated data includes the active power and reactive power of the boundary nodes. However, in order to perform iterative calculations for grid dispatch, it is also necessary to obtain the voltage amplitude and voltage phase angle of the boundary nodes. In some embodiments of the present invention, this is obtained by obtaining the boundary node data from the previous iteration. In other embodiments, the voltage amplitude and voltage phase angle of the boundary nodes can be vector-merged with the calculated active power and reactive power to obtain a vector including active power, reactive power, voltage amplitude, and voltage phase angle, which serves as the first updated data.

[0104] Further, preferably, if the current iteration is the first iteration, the step of obtaining the second update data from the previous iteration when receiving first update data from at least S power distribution systems during the current iteration includes:

[0105] Obtain initial boundary node data;

[0106] In the current iteration, when the first update data is received from at least S power distribution systems, the initial boundary node data is used as the second update data in the previous iteration.

[0107] It should be noted that, in this embodiment of the invention, the power grid needs to be initialized before the power grid dispatch calculation. Specifically, the boundary node data, Lagrange multipliers, control variables, and state variables of the transmission system and distribution system are initialized respectively. Initializing the boundary node data provides an initial state for iterative calculation.

[0108] For example, the voltage magnitude V at the boundary node in the power grid is initialized. B The voltage phase angle is initialized to 1.0 pu. B The initial value is 0 degrees. Then, based on the system's load distribution and generation plan, active and reactive power are injected into the boundary nodes. The Lagrange multiplier λ is set. (0) =0. Initialize control variables based on historical operating data, and calculate initial state variables based on preliminary power flow.

[0109] Initial boundary node data provides an initial state for subsequent iterative calculations, enabling the system to gradually approach the true optimal solution in later iterations. Lagrange multipliers are bilateral constraints used to coordinate boundary variables between the transmission and distribution systems; initializing the Lagrange multipliers can accelerate the convergence of the initial iterations. The control variables include generator output, transformer turns ratio, and setpoints for reactive power compensation devices; the state variables include voltage amplitude and phase angle at each node, and line power flow.

[0110] In some embodiments, as a preferred implementation, updating the first update data using a forward-backward operator splitting algorithm based on the first update data and the second update data from the previous iteration to obtain the second update data for the current iteration includes:

[0111] Based on the first updated data and the second updated data in the previous iteration, calculate the current global vector of the boundary node between the power transmission system and the power distribution system;

[0112] Calculate the power flow value of the transmission system based on the current global vector;

[0113] Based on the power flow value, the forward-backward operator splitting algorithm is used to update the current global vector to obtain the updated global variable;

[0114] Based on the updated global variable, the second updated data for the current iteration is obtained.

[0115] It should be noted that the current global variable can be vector data of boundary nodes that have a consistent relationship between the transmission system and all the distribution systems, or it can be vector data of boundary nodes between the transmission system and a specific distribution system. However, it is necessary to ensure that when the generated second update data is sent to the distribution system, it can at least enable the specific distribution system to perform iterative calculations.

[0116] For example, via x t+1 =(1-η)x t +ηT(x transmit ), The first updated data is updated to obtain the second updated data;

[0117] Where, x t+1 For the second update data; η∈[0,1]; x t For the first updated data, x transmit T is the current global variable, and T(·) is the power flow calculation function; a t,j x represents the additional error of the j-th power distribution system; t,jFor the first update data of the j-th power distribution system, x t-l,j The first update data when removing the effect of the lag step l for the j-th power distribution system.

[0118] In a preferred embodiment, prior to step S1, the power grid dispatching method further includes:

[0119] Obtain the lag step count for each of the power distribution systems; the lag step count for each of the power distribution systems is updated after each iteration;

[0120] The power distribution system with a lag step number of not less than τ is defined as a lag power distribution system;

[0121] Therefore, the at least S power distribution systems include lagging power distribution systems.

[0122] It should be noted that the lag step number represents the difference between the arrival time of data updates in the distribution system and the data update time in the transmission system. By setting the maximum lag parameter τ, it can be ensured that each distribution system updates its data at least once within τ iterations.

[0123] More preferably, in some embodiments, a global clock for the power transmission system and a local clock for the power distribution system are preset, and the global clock and the local clock are always incremented simultaneously with each iteration.

[0124] Further, preferably, the method for updating the lag step count of each of the power distribution systems includes:

[0125] If the first update data received during the current iteration comes from a power distribution system, then the lag step count of that power distribution system is reset after the current iteration.

[0126] If the first update data received in the current iteration does not come from a power distribution system, then the lag step number of the power distribution system is incremented after the current iteration.

[0127] Please see Figure 2In this embodiment, five power distribution systems are shown, with τ = 8. The transmission network time is a preset clock signal that applies simultaneously to both the transmission system and all power distribution systems. For power distribution system 4, during transmission network times 1-2, the transmission system receives the first update data from all power distribution systems. Therefore, the transmission system performs a data update and iteration once each during transmission network times 1 and 2, and resets the lag step count for all power distribution systems. During transmission network times 3-5, the transmission system can receive the first update data from all distribution systems except distribution system 4, and the quantity is greater than the preset S. Therefore, the transmission system performs a data update and iteration once each at transmission network times 3, 4, and 5, and increments the lag step of distribution system 4 by 1 at each distribution network time. The lag step of the unupdated distribution system 4 relative to the transmission system at transmission network time 5 is 3. During transmission network times 6-9, the transmission system can only receive the first update data from distribution system 1 and distribution system 5, and the quantity meets the preset S. Therefore, the transmission system performs a data update and iteration once each at transmission network times 6, 7, 8, and 9. The lag step of the unupdated distribution system 4 relative to the transmission system at transmission network time 9 is 7, and the lag step of the unupdated distribution systems 2 and 3 relative to the transmission system at transmission network time 9 is 4. Therefore, after the transmission network time 9, it is necessary to wait for the first update data of the distribution system 4 to arrive before the data update and iteration of the transmission system can be carried out; otherwise, the lag step number of the distribution system 4 will be equal to τ.

[0128] Please see Figure 3 At time k = 0, distribution systems 1-5 begin updating their data. Distribution systems 2 and 3 complete their data updates and data transmission first. When the transmission system receives the first update data from distribution systems 2 and 3, it begins the first iteration. Then, the transmission system receives the first update data from distribution systems 4 and 5 and begins the second iteration. In the third iteration, although the transmission system has received the first update data from distribution systems 2 and 3, distribution system 1 has not yet completed data transmission, and its lag step has reached 2. Therefore, it needs to wait for distribution system 1 to complete its data transmission. When the transmission system receives the first update data from distribution system 1, it begins the third iteration.

[0129] As a preferred implementation, step S2, calculating the power flow value based on the second updated data, and determining whether the power flow value meets the iteration termination condition, includes:

[0130] The power flow value is calculated based on the second updated data; the power flow value includes the first power flow value of the transmission system and the second power flow value of each of the distribution systems.

[0131] Determine the convergence of the power flow values ​​of the power grid;

[0132] If the power flow value does not converge, it is considered that the power flow value does not meet the iteration termination condition;

[0133] If the power flow value converges, it is considered that the power flow value satisfies the iteration termination condition.

[0134] It should be noted that power flow values ​​are fundamental to power system operation and planning, depicting the operating state of the power system and providing crucial reference for system operation and planning. To better facilitate power grid dispatch planning, the optimization objectives of both the transmission and distribution systems are considered when calculating these power flow values. Specifically, a weighting factor ω is introduced, and a comprehensive objective is generated based on the optimization objectives of both the transmission and distribution systems. in, For the optimization goal of the power transmission system, Let be the minimum value of the central objective function of the power transmission system. This represents the maximum value of the central objective function of the power transmission system. For the optimization goal of the power distribution system, To minimize the central objective function of the power distribution system. This represents the maximum value of the central objective function of the power distribution system.

[0135] It should be noted that the iteration is implemented in the interaction between the transmission system and the distribution system. In the iteration process, the transmission system first sends the initial Lagrange multipliers and initial boundary node data to the distribution system. Then, the distribution system generates the first update data based on the received data and sends the first update data to the transmission system. The transmission system then determines the convergence of the power flow based on the first update data. If it does not converge, it generates the second update data and sends it to the distribution system; otherwise, it obtains the scheduling data.

[0136] For example, when the distribution system receives the initial Lagrange multipliers and initial boundary node data from the transmission system, it solves the distribution subproblem. The solution process uses g... D (u D ,x D ,y D By setting the constraint ) = 0, the first updated data is obtained. Among them, u D As a control variable, x D Let y be a state variable. D These are the state variables for the boundary nodes. When solving the distribution subproblem, the initial Lagrange multipliers are updated.

[0137] When the transmission system receives at least S first update data from the distribution center, the transmission subproblem is solved by λ. t+1 =λ t +η(h t+1 -h t Update the Lagrange multipliers; via stg T (u T ,x T ,y T The second updated data is obtained when ) = 0, where u T As a control variable, x T Let y be a state variable. T These are the state variables for the boundary nodes.

[0138] Furthermore, as a preferred embodiment, the step of calculating the power flow value based on the second updated data includes:

[0139] The voltage amplitude, voltage phase angle, active power, and reactive power of the boundary node between the power transmission system and the power distribution system are obtained based on the second updated data.

[0140] Calculate the first power flow value of the transmission system based on the voltage amplitude and the voltage phase angle;

[0141] Calculate the second power flow value for each of the power distribution systems based on the active power and the reactive power;

[0142] The power grid power flow value is obtained based on the first power flow value and the second power flow value.

[0143] For example, via T φ ([V B ;θ B ])=[P B ′ Q ′ B ] Calculate the first power flow value of the transmission system; through D φ ([P B Q B ])=[V′ B ;θ′ B Calculate the second power flow value of the transmission system; where P′ B Active power; Q′ B Reactive power; V′ B For voltage amplitude; θ′ B This is the voltage phase angle.

[0144] Preferably, determining the convergence of the power flow value includes:

[0145] The spectral radius index is calculated based on the power flow value of the power grid.

[0146] When the spectral radius index is less than 1, the power flow value is determined to be converged; otherwise, the power flow value is determined to be non-converged.

[0147] For example, by The spectral radius index is obtained, where T φ D represents the first power flow value of the transmission system. φ The second power flow value of the power distribution system; x = [P B Q B V B ;θ B ].

[0148] The asynchronous power grid scheduling method for transmission and distribution coordination provided in this embodiment of the invention decomposes the computational tasks of the transmission system and the distribution system, and uses an asynchronous forward-backward operator splitting algorithm to handle the problems of the transmission system and the distribution system respectively, which can significantly improve the overall computational efficiency and operational stability of the integrated transmission and distribution system.

[0149] Please see Figure 4 This invention provides an asynchronous power grid dispatching system for transmission and distribution coordination, including a data update module 11, an iteration end judgment module 12, a data transmission module 13, and a power grid dispatching module 14, wherein:

[0150] Data update module 11 is used to calculate second update data using a forward-backward operator splitting algorithm when receiving first update data from at least S power distribution systems during the current iteration; both the first update data and the second update data include boundary node data between the power transmission system and the power distribution system;

[0151] The iteration end judgment module 12 is used to calculate the power flow value based on the second updated data and determine whether the power flow value meets the iteration end condition.

[0152] The data sending module 13 is used to send the second update data to the power distribution system if no, so that the power distribution system can issue first update data for the next iteration based on the second update data;

[0153] The power grid dispatching module 14 is used to obtain dispatching data based on the power grid flow value if the condition is met, and to perform power grid dispatching based on the dispatching data.

[0154] In a preferred embodiment, the data update module 11 includes:

[0155] The previous iteration data acquisition unit is used to acquire the second update data in the previous iteration when it receives the first update data from at least S power distribution systems;

[0156] The current iteration data update unit is used to update the first update data according to the first update data and the second update data in the previous iteration, using a forward-backward operator splitting algorithm to obtain the second update data for the current iteration.

[0157] Further, preferably, if the current iteration is the first iteration, the previous iteration data acquisition unit is specifically used for:

[0158] Obtain initial boundary node data;

[0159] When the first update data is received from at least S power distribution systems, the initial boundary node data is used as the second update data in the previous iteration.

[0160] Preferably, the current iteration data update unit is specifically used for:

[0161] Based on the first updated data and the second updated data in the previous iteration, calculate the current global vector of the boundary node between the power transmission system and the power distribution system;

[0162] Calculate the power flow value of the transmission system based on the current global vector;

[0163] Based on the power flow value, the forward-backward operator splitting algorithm is used to update the current global vector to obtain the updated global variable;

[0164] Based on the updated global variable, the second updated data for the current iteration is obtained.

[0165] In a preferred embodiment, the power grid dispatching system further includes:

[0166] The lag step acquisition module is used to acquire the lag step count of each of the power distribution systems; the lag step count of each of the power distribution systems is updated after each iteration;

[0167] A power distribution system screening module is used to identify power distribution systems with a lag step number of not less than τ as lag power distribution systems.

[0168] Therefore, the at least S power distribution systems include lagging power distribution systems.

[0169] Further, preferably, the method for updating the lag step count of each of the power distribution systems includes:

[0170] If the first update data received during the current iteration comes from a power distribution system, then the lag step count of that power distribution system is reset after the current iteration.

[0171] If the first update data received in the current iteration does not come from a power distribution system, then the lag step number of the power distribution system is incremented after the current iteration.

[0172] In a preferred embodiment, the iteration end determination module 12 includes:

[0173] A power flow calculation unit is used to calculate a power flow value based on the second updated data; the power flow value includes a first power flow value of the transmission system and a second power flow value of each of the distribution systems.

[0174] A convergence determination unit is used to determine the convergence of the power flow value of the power grid.

[0175] The first convergence determination unit is used to determine that if the power grid power flow value does not converge, the power grid power flow value does not meet the iteration termination condition.

[0176] The second convergence determination unit is used to determine if the power grid power flow value converges, and then consider that the power grid power flow value meets the iteration termination condition.

[0177] Furthermore, as a preferred embodiment, the power flow value calculation unit is specifically used for:

[0178] The voltage amplitude, voltage phase angle, active power, and reactive power of the boundary node between the power transmission system and the power distribution system are obtained based on the second updated data.

[0179] Calculate the first power flow value of the transmission system based on the voltage amplitude and the voltage phase angle;

[0180] Calculate the second power flow value for each of the power distribution systems based on the active power and the reactive power;

[0181] The power grid power flow value is obtained based on the first power flow value and the second power flow value.

[0182] Preferably, the convergence determination unit is specifically used for:

[0183] The spectral radius index is calculated based on the power flow value of the power grid.

[0184] When the spectral radius index is less than 1, the power flow value is determined to be converged; otherwise, the power flow value is determined to be non-converged.

[0185] The asynchronous power grid dispatching system for transmission and distribution coordination provided in this embodiment of the invention decomposes the computational tasks of the transmission system and the distribution system, and uses an asynchronous forward-backward operator splitting algorithm to handle the problems of the transmission system and the distribution system respectively, which can significantly improve the overall computational efficiency and operational stability of the integrated transmission and distribution system.

[0186] This invention also provides an asynchronous power grid dispatching device for transmission and distribution coordination. The power grid dispatching device includes a processor, a memory, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the steps in the various power grid dispatching method embodiments described above, such as steps S1 to S4.

[0187] For example, the computer program may be divided into one or more modules / units, which are stored in the memory and executed by the processor to complete the present invention. The one or more modules / units may be a series of computer program instruction segments capable of performing a specific function, which describe the execution process of the computer program in the power grid dispatching equipment.

[0188] The power grid dispatching equipment may include, but is not limited to, processors and memory. Those skilled in the art will understand that the schematic diagram is merely an example of a power grid dispatching device and does not constitute a limitation on the device. It may include more or fewer components than illustrated, or combine certain components, or use different components. For example, the power grid dispatching device may also include input / output devices, network access devices, buses, etc.

[0189] The processor can be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. The general-purpose processor can be a microprocessor or any conventional processor. The processor is the control center of the power grid dispatching equipment, connecting various parts of the entire power grid dispatching equipment through various interfaces and lines.

[0190] The memory can be used to store the computer programs and / or modules. The processor implements various functions of the power grid dispatching equipment by running or executing the computer programs and / or modules stored in the memory and by calling the data stored in the memory. The memory may mainly include a program storage area and a data storage area. The program storage area may store the operating system, at least one application program required for a function (such as sound playback function, image playback function, etc.), etc.; the data storage area may store data created based on the use of the mobile phone (such as audio data, phonebook, etc.). In addition, the memory may include high-speed random access memory, and may also include non-volatile memory, such as hard disk, memory, plug-in hard disk, smart media card (SMC), secure digital (SD) card, flash card, at least one disk storage device, flash memory device, or other volatile solid-state storage device.

[0191] If the integrated modules / units of the power grid dispatching equipment are implemented as software functional units and sold or used as independent products, they can be stored in a computer-readable storage medium. Based on this understanding, all or part of the processes in the above embodiments of the present invention can also be implemented by a computer program instructing related hardware. The computer program can be stored in a computer-readable storage medium, and when executed by a processor, it can implement the steps of the various method embodiments described above. The computer program includes computer program code, which can be in the form of source code, object code, executable files, or certain intermediate forms. The computer-readable medium can include: any entity or device capable of carrying the computer program code, recording media, USB flash drives, portable hard drives, magnetic disks, optical disks, computer memory, read-only memory (ROM), random access memory (RAM), electrical carrier signals, telecommunication signals, and software distribution media, etc.

[0192] 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 program can be stored in a computer-readable storage medium, and when executed, it can include the processes of the embodiments of the above methods. The storage medium can be a magnetic disk, optical disk, read-only memory (ROM), or random access memory (RAM), etc.

[0193] The above description represents the preferred embodiments of the present invention. It should be noted that those skilled in the art can make various improvements and modifications without departing from the principles of the present invention, and these improvements and modifications are also considered to be within the scope of protection of the present invention.

Claims

1. An asynchronous power grid dispatching method for transmission and distribution coordination, applied to a power transmission system, characterized in that, include: In the current iteration, when the first update data is received from at least S power distribution systems, the second update data is calculated using the forward-backward operator splitting algorithm. Both the first updated data and the second updated data include boundary node data between the power transmission system and the power distribution system; Based on the second updated data, the power flow value is calculated, and it is determined whether the power flow value meets the iteration termination condition. If not, the second update data is sent to the power distribution system so that the power distribution system issues first update data for the next iteration based on the second update data. If so, then dispatch data is obtained based on the power flow value, and power grid dispatch is performed based on the dispatch data; In the current iteration, when first update data is received from at least S power distribution systems, a forward-backward operator splitting algorithm is used to calculate second update data, including: During the current iteration, when first update data is received from at least S power distribution systems, the second update data from the previous iteration is obtained; Based on the first updated data and the second updated data in the previous iteration, the first updated data is updated using the forward-backward operator splitting algorithm to obtain the second updated data for the current iteration; If the current iteration is the first iteration, the step of obtaining the second update data from the previous iteration when receiving first update data from at least S power distribution systems during the current iteration includes: Obtain initial boundary node data; During the current iteration, when the first update data is received from at least S power distribution systems, the initial boundary node data is used as the second update data in the previous iteration; The step of updating the first update data using a forward-backward operator splitting algorithm based on the first update data and the second update data from the previous iteration to obtain the second update data for the current iteration includes: Based on the first updated data and the second updated data in the previous iteration, calculate the current global vector of the boundary node between the power transmission system and the power distribution system; Calculate the power flow value of the transmission system based on the current global vector; Based on the power flow value, the forward-backward operator splitting algorithm is used to update the current global vector to obtain the updated global variable; Based on the updated global variable, the second updated data for the current iteration is obtained.

2. The asynchronous power grid dispatching method with transmission and distribution coordination as described in claim 1, characterized in that, In the current iteration process, before calculating the second update data using the forward-backward operator splitting algorithm after receiving first update data from at least S distribution systems, the power grid dispatching method further includes: Obtain the lag step count for each of the power distribution systems; the lag step count for each of the power distribution systems is updated after each iteration; The power distribution system with a lag step number of not less than τ is defined as a lag power distribution system; Therefore, the at least S power distribution systems include lagging power distribution systems.

3. The asynchronous power grid dispatching method with transmission and distribution coordination as described in claim 2, characterized in that, The method for updating the lag step count for each of the aforementioned power distribution systems includes: If the first update data received during the current iteration comes from a power distribution system, then the lag step count of that power distribution system is reset after the current iteration. If the first update data received in the current iteration does not come from a power distribution system, then the lag step number of the power distribution system is incremented after the current iteration.

4. The asynchronous power grid dispatching method with transmission and distribution coordination as described in claim 1, characterized in that, The step of calculating the power flow value based on the second updated data and determining whether the power flow value meets the iteration termination condition includes: The power flow value is calculated based on the second updated data; the power flow value includes the first power flow value of the transmission system and the second power flow value of each of the distribution systems. Determine the convergence of the power flow values ​​of the power grid; If the power flow value does not converge, it is considered that the power flow value does not meet the iteration termination condition; If the power flow value converges, it is considered that the power flow value satisfies the iteration termination condition.

5. The asynchronous power grid dispatching method for transmission and distribution coordination as described in claim 4, characterized in that, The calculation of the power flow value based on the second updated data includes: The voltage amplitude, voltage phase angle, active power, and reactive power of the boundary node between the power transmission system and the power distribution system are obtained based on the second updated data. Calculate the first power flow value of the transmission system based on the voltage amplitude and the voltage phase angle; Calculate the second power flow value for each of the power distribution systems based on the active power and the reactive power; The power grid power flow value is obtained based on the first power flow value and the second power flow value.

6. The asynchronous power grid dispatching method for transmission and distribution coordination as described in claim 4, characterized in that, The determination of the convergence of the power flow value includes: The spectral radius index is calculated based on the power flow value of the power grid. When the spectral radius index is less than 1, the power flow value is determined to be converged; otherwise, the power flow value is determined to be non-converged.

7. An asynchronous power grid dispatching system for transmission and distribution coordination, applied to a power transmission system, characterized in that, include: The data update module is used to calculate the second update data using a forward-backward operator splitting algorithm when receiving the first update data from at least S power distribution systems during the current iteration; both the first update data and the second update data include the boundary node data between the power transmission system and the power distribution system; The iteration end judgment module is used to calculate the power flow value based on the second updated data and determine whether the power flow value meets the iteration end condition. The data sending module is configured to send the second update data to the power distribution system if not, so that the power distribution system can issue first update data for the next iteration based on the second update data. The power grid dispatching module is used to obtain dispatching data based on the power grid flow value if the condition is met, and to perform power grid dispatching based on the dispatching data. The data update module includes: The previous iteration data acquisition unit is used to acquire the second update data in the previous iteration when it receives the first update data from at least S power distribution systems; The current iteration data update unit is used to update the first update data according to the first update data and the second update data in the previous iteration using a forward-backward operator splitting algorithm to obtain the second update data for the current iteration; The previous iteration data acquisition unit is specifically used for: Obtain initial boundary node data; When the first update data is received from at least S power distribution systems, the initial boundary node data is used as the second update data in the previous iteration; The current iteration data update unit is specifically used for: Based on the first updated data and the second updated data in the previous iteration, calculate the current global vector of the boundary node between the power transmission system and the power distribution system; Calculate the power flow value of the transmission system based on the current global vector; Based on the power flow value, the forward-backward operator splitting algorithm is used to update the current global vector to obtain the updated global variable; Based on the updated global variable, the second updated data for the current iteration is obtained.

8. The asynchronous power grid dispatching system for transmission and distribution coordination as described in claim 7, characterized in that, The power grid dispatching system also includes: The lag step acquisition module is used to acquire the lag step count of each of the power distribution systems; the lag step count of each of the power distribution systems is updated after each iteration; A power distribution system screening module is used to identify power distribution systems with a lag step number of not less than τ as lag power distribution systems. Therefore, the at least S power distribution systems include lagging power distribution systems.

9. The asynchronous power grid dispatching system for transmission and distribution coordination as described in claim 8, characterized in that, The method for updating the lag step count for each of the aforementioned power distribution systems includes: If the first update data received during the current iteration comes from a power distribution system, then the lag step count of that power distribution system is reset after the current iteration. If the first update data received in the current iteration does not come from a power distribution system, then the lag step number of the power distribution system is incremented after the current iteration.

10. The asynchronous power grid dispatching system with transmission and distribution coordination as described in claim 7, characterized in that, The iteration end determination module includes: A power flow calculation unit is used to calculate a power flow value based on the second updated data; the power flow value includes a first power flow value of the transmission system and a second power flow value of each of the distribution systems. A convergence determination unit is used to determine the convergence of the power flow value of the power grid. The first convergence determination unit is used to determine that if the power grid power flow value does not converge, the power grid power flow value does not meet the iteration termination condition. The second convergence determination unit is used to determine if the power grid power flow value converges, and then consider that the power grid power flow value meets the iteration termination condition.

11. The asynchronous power grid dispatching system for transmission and distribution coordination as described in claim 10, characterized in that, The power flow value calculation unit is specifically used for: The voltage amplitude, voltage phase angle, active power, and reactive power of the boundary node between the power transmission system and the power distribution system are obtained based on the second updated data. Calculate the first power flow value of the transmission system based on the voltage amplitude and the voltage phase angle; Calculate the second power flow value for each of the power distribution systems based on the active power and the reactive power; The power grid power flow value is obtained based on the first power flow value and the second power flow value.

12. The asynchronous power grid dispatching system for transmission and distribution coordination as described in claim 10, characterized in that, The convergence determination unit is specifically used for: The spectral radius index is calculated based on the power flow value of the power grid. When the spectral radius index is less than 1, the power flow value is determined to be converged; otherwise, the power flow value is determined to be non-converged.

13. An asynchronous power grid dispatching device for transmission and distribution coordination, characterized in that, It includes a processor, a memory, and a computer program stored in the memory and configured to be executed by the processor, wherein the processor executes the computer program to implement an asynchronous grid dispatching method for transmission and distribution coordination as described in any one of claims 1 to 6.

14. A computer-readable storage medium, characterized in that, The computer-readable storage medium includes a stored computer program, wherein, when the computer program is executed, it controls the device where the computer-readable storage medium is located to perform an asynchronous power grid dispatching method for transmission and distribution coordination as described in any one of claims 1 to 6.

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