A grid-province AGC collaborative optimization control method and system considering power grid safety constraints

Abstract

A grid-province AGC collaborative optimization control method and system considering power grid safety constraints, comprising: calculating the original regional control deviation of the corresponding provincial power grid based on the frequency of the provincial power grid, the actual active power value and the active power plan value of the tie line with other provincial power grids, calculating the target value of the regional control deviation correction amount based on the original regional control deviation of each provincial power grid and the sum of the original regional control deviations of all provincial power grids; establishing a grid-province AGC collaborative optimization control model, using a linear programming method to solve the actual correction amount of the regional control deviation allocated to each provincial power grid, calculating the corrected regional control deviation, and the provincial AGC system controlling the active power control of the frequency regulating unit based on the corrected regional control deviation. The present application can guide the grid-province collaborative AGC strategy making considering the power grid safety constraints, and provide technical support for improving the frequency control performance and operation safety of large power grids.

Description

Technical Field

[0001] This invention relates to technologies related to power system operation and control, specifically to a grid-province AGC collaborative optimization control method and system that considers grid security constraints. Background Technology

[0002] Traditional provincial power grid TBC control mode follows a "separate control" logic, failing to fully consider the mismatch between control capabilities and frequency regulation requirements in different control areas due to differences in power grid structure. This control method can achieve power balance in each control area when the system power imbalance is small and resources are sufficient, but it lacks adaptability when the system power imbalance is large and resources are insufficient in each control area.

[0003] In recent years, with the rapid development of ultra-high-voltage AC / DC power transmission and the large-scale grid connection of new energy sources, the operating characteristics of power systems have undergone profound changes. On the one hand, ultra-high-voltage power grids have led to more frequent inter-regional power exchange, reduced system inertia, and a significant increase in frequency regulation requirements. On the other hand, the randomness and volatility of new energy output have exacerbated the uncertainty of system power, posing a severe challenge to the traditional single-area independent control mode. Against this backdrop, breaking away from the traditional fragmented control approach and achieving coordinated control between different control areas is not only a requirement for efficiency improvement but also an urgent need to ensure the safe and stable operation of the system. How to fully leverage the complementary advantages of regulation resources in each control area while ensuring control accuracy has become a key issue that urgently needs to be addressed in the field of power system frequency control.

[0004] To address the aforementioned issues, scholars and power dispatching agencies both domestically and internationally have conducted extensive research, proposing various coordinated control methods for control areas. For example, the International Grid Control Cooperation (IGCC) model in Europe achieves frequency regulation reserve sharing through multi-country interconnection, reducing overall reserve capacity requirements. However, in actual operation, it is prone to reverse regulation due to inconsistent regulation directions, which deteriorates frequency quality. The American ACE Differential Exchange (ADI) method is simple and easy to implement, but it uses fixed transmission line power limits and lacks dynamic adaptability to system operating conditions, limiting further improvement in its coordination effect. The dynamic ACE method proposed by the East China Power Grid in my country mainly targets coordinated control under specific fault scenarios. While it improves frequency recovery after faults to some extent, it is difficult to meet the continuous frequency coordinated control requirements of daily operation. Overall, existing methods are insufficient to fully adapt to the frequency regulation requirements of power systems under the new circumstances, necessitating research into more efficient and flexible cross-regional coordinated control strategies. Summary of the Invention

[0005] The purpose of this invention is to provide a grid-province AGC collaborative optimization control method and system that takes into account grid security constraints. This solution can solve the problems of existing grid-province AGC coordinated control methods not fully considering the collaborative mechanism between multiple control areas under daily operation, lacking full utilization of frequency regulation reserve resources, and lacking dynamic adaptability to grid security constraints such as line power flow. It also solves the problem that existing methods cannot balance frequency regulation quality and frequency regulation reserve cost when dealing with grid disturbances.

[0006] The present invention adopts the following technical solution.

[0007] The first aspect of this invention proposes a grid-province AGC collaborative optimization control method considering grid security constraints, comprising:

[0008] The frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids, the planned active power value and the tie line power limit are obtained through the AGC system of each province. Based on the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids and the planned active power value, the original regional control deviation of the corresponding provincial power grid is calculated and uploaded to the grid dispatch AGC system.

[0009] In the grid dispatch AGC system, based on the original regional control deviation of each provincial power grid and the sum of the original regional control deviations of all provincial power grids, the target value of the regional control deviation correction amount is calculated and distributed to each provincial dispatch AGC system through positive and negative relationship judgment and proportional allocation.

[0010] An objective function is constructed based on the target value of the regional control deviation correction and the corrected regional control deviation. At the same time, a constraint function considering grid security constraints is constructed based on the tie-line power limit, thereby establishing a grid-province AGC collaborative optimization control model.

[0011] Based on the constructed grid-province AGC collaborative optimization control model, the actual correction amount of the regional control deviation allocated to each provincial power grid is solved by linear programming. The actual correction amount of the regional control deviation is then sent to each provincial dispatch AGC system to calculate the corrected regional control deviation. Each provincial dispatch AGC system performs active power control on its frequency regulation units based on the corrected regional control deviation.

[0012] Preferably, the original regional control deviation of the corresponding provincial power grid is calculated based on the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids, and the planned active power value, specifically as follows:

[0013] For each provincial power grid, the negative product of the difference between the corresponding frequency and the rated frequency and the frequency deviation coefficient, plus the difference between the actual active power value and the planned active power value of all other provincial power grids connected to the corresponding provincial power grid via tie lines, yields the original regional control deviation of the corresponding provincial power grid.

[0014] Preferably, the target value of the regional control deviation correction amount distributed to each provincial AGC system is calculated and allocated based on the positive / negative relationship and proportional allocation, specifically as follows:

[0015] When the original regional control deviations of each provincial power grid have opposite positive and negative signs, the target value of the ACE correction for each region is calculated by proportional allocation based on the original regional control deviations of each provincial power grid with different positive and negative signs and the sum of the original regional control deviations of all provincial power grids; when the positive and negative signs of the original regional control deviations of all provincial power grids are the same, the target value of the correction for all regional control deviations is 0.

[0016] Preferably, when there are cases where the positive and negative signs of the original regional control deviations in each provincial power grid are opposite, the target value of the regional control deviation correction is calculated by proportional allocation, specifically as follows:

[0017] First, calculate the sum of the original regional control deviations of all provincial power grids;

[0018] For each provincial power grid, if the original regional control deviation of the provincial power grid is of opposite sign to the sum of the original regional control deviations of all provincial power grids, then the target value of the regional control deviation correction for that provincial power grid is the original regional control deviation of the provincial power grid with a negative sign; the number of provincial power grids corresponding to this opposite sign is... k ;

[0019] Otherwise, if the original regional control deviation of the provincial power grid and the sum of the original regional control deviations of all provincial power grids have the same sign, the target value of the regional control deviation correction shall be calculated according to the proportional allocation principle.

[0020] Preferably, if the original regional control deviation of a provincial power grid and the sum of the original regional control deviations of all provincial power grids have the same sign, then the target value of the regional control deviation correction is calculated according to the proportional allocation principle, specifically as follows:

[0021] If the original regional control deviations of the corresponding provincial power grids and the sum of the original regional control deviations of all provincial power grids are both positive, then the original regional control deviations of all provincial power grids are sorted in ascending order.

[0022] Add up the positive deviations from the original regional control deviations of all provincial power grids to get the total positive deviations; then add up the negative deviations to get the total negative deviations.

[0023] For the k +1 to the N -1 provincial power grid, N For the total number of provincial power grids, the target value for the regional control deviation correction of the corresponding provincial power grid is the product of the proportion of the original regional control deviation of the corresponding provincial power grid in the total positive deviation and the total negative deviation; if the calculated number of... k +1 to the N If the target value of the regional control deviation correction for a provincial power grid is not an integer, it will be rounded to the nearest integer.

[0024] No. N The target value for the regional control deviation correction of a provincial power grid is the sum of all original regional control deviations with negative signs minus the first... k +1 to the N -1 The sum of the target values ​​of the regional control deviation correction for a provincial power grid;

[0025] If the original regional control deviations of the corresponding provincial power grids and the sum of the original regional control deviations of all provincial power grids are both negative, then the original regional control deviations of all provincial power grids are sorted from largest to smallest. For the th k +1 to the N -1 provincial power grids, the target value of the regional control deviation correction for the corresponding provincial power grid is the product of the proportion of the original regional control deviation in the total negative deviations and the total positive deviations; if the calculated number of... k +1 to the N If the target value of the regional control deviation correction for a provincial power grid is not an integer, it will be rounded to the nearest integer.

[0026] No. N The target value for the regional control deviation correction of a provincial power grid is the sum of all original regional control deviations with positive signs minus the first... k +1 to the N -1 is the sum of the target values ​​of the regional control deviation correction for a provincial power grid.

[0027] Preferably, the objective function is constructed based on the target value of the area control deviation correction and the corrected area control deviation, specifically as follows:

[0028] Objective function of the collaborative optimization control model of AGC in the network province f It consists of two sub-objective functions with different priorities. f 1. f 2. Composition, the first sub-objective function f 1 is the sum of the actual correction amount of the control deviation in each region and the absolute value of the corresponding target value deviation;

[0029] Second sub-objective functionf 2. To minimize the sum of the absolute values ​​of each corrected regional control deviation, the corrected regional control deviation is the original regional control deviation plus the actual correction amount of the corresponding regional control deviation.

[0030] Preferably, a constraint function considering grid security constraints is constructed based on the tie-line power limit, specifically as follows:

[0031] The tie line power limits include the maximum power of the tie line in the negative direction and the maximum power of the tie line in the positive direction.

[0032] The first constraint is: the sum of the actual corrections for all area control deviations is 0.

[0033] The second constraint is: for each tie line, the current value of the tie line apparent power plus the product of all corrected area control deviations and the corresponding power transmission distribution factor, the sum of which is greater than or equal to the maximum power of the tie line negative power and less than or equal to the maximum power of the tie line positive power.

[0034] The power transmission distribution factor is the power change caused by the change in unit active power of the provincial power grid corresponding to the corrected regional control deviation on the corresponding tie line.

[0035] The third constraint is that the sum of the apparent power of all tie lines connected to the provincial power grid is equal to the net power injection of the corresponding provincial power grid.

[0036] Preferably, based on the constructed provincial-level AGC collaborative optimization control model, the actual correction amount of the regional control deviation allocated to each provincial power grid is solved using a linear programming method, specifically as follows:

[0037] The first step is to define the objective function. f The formula in step 1 is transformed into a linear function, which is then solved using a linear programming solver.

[0038] If the first step yields a unique solution, the second step is discontinued, and the actual correction values ​​for the regional control deviations of each provincial power grid, obtained in the first step, are distributed to the respective provincial dispatch AGC systems. If the first step yields two or more solutions, the second step continues, and the objective function is... f Formula 2 is transformed into a linear function, and based on the objective function... f The optimal value of 1 is given an additional constraint, which is solved using a linear programming solver.

[0039] If a unique solution is obtained in the second step, the actual correction amount of the regional control deviation of each provincial power grid obtained in the second step is sent to the provincial dispatch AGC system. If two or more solutions appear in the second step, a set of actual correction amounts of the regional control deviation of each provincial power grid is selected from the optimal solution set of the second step and sent to the provincial dispatch AGC system.

[0040] Preferably, the objective function f The formula in step 1 is transformed into a linear function, which is then solved using a linear programming solver, specifically:

[0041] For each provincial power grid, two non-negative variables are defined as the first non-negative variable and the second non-negative variable. Let the actual correction amount of the regional control deviation of the corresponding provincial power grid minus the target value of the corresponding regional control deviation correction amount be equal to the first non-negative variable minus the second non-negative variable.

[0042] objective function f The formula in step 1 is transformed into a linear function that minimizes the sum of the first and second non-negative variables corresponding to all provincial power grids.

[0043] Preferably, the objective function f Formula 2 is transformed into a linear function, and based on the objective function... f The optimal value of 1 is subject to an additional constraint, specifically:

[0044] For each provincial power grid, two non-negative variables are defined as the third non-negative variable and the fourth non-negative variable. The corrected regional control deviation of the corresponding provincial power grid is equal to the third non-negative variable minus the fourth non-negative variable.

[0045] objective function f Formula 2 can be transformed into a linear function that minimizes the sum of the third and fourth non-negative variables corresponding to all provincial power grids;

[0046] The added constraint is that the sum of the difference between the actual correction amount of the regional control deviation of all provincial power grids and the target value of the corresponding regional control deviation correction amount is less than or equal to the optimal value of the objective function.

[0047] A second aspect of the present invention proposes a grid-province AGC collaborative optimization control system based on the method described in the first aspect of the present invention, considering grid security constraints, comprising: a data acquisition module, a data preprocessing module, a model building module, a model solving module, and a real-time control module, specifically:

[0048] Data acquisition module: used to obtain the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids, the planned active power value and the tie line power limit through the AGC system of each provincial dispatch center; based on the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids and the planned active power value, calculate the original regional control deviation of the corresponding provincial power grid, and upload the original regional control deviation to the grid dispatch AGC system;

[0049] Data preprocessing module: In the grid dispatch AGC system, based on the original regional control deviation of each provincial power grid and the sum of the original regional control deviations of all provincial power grids, the target value of the regional control deviation correction amount to be sent to each provincial dispatch AGC system is calculated by judging the positive and negative relationship and proportional allocation.

[0050] Model building module: used to construct an objective function based on the target value of the regional control deviation correction and the corrected regional control deviation, and at the same time to construct a constraint function based on the tie line power limit that takes into account the power grid safety constraints, thereby establishing a grid-province AGC collaborative optimization control model;

[0051] Model Solving Module: Based on the constructed provincial AGC collaborative optimization control model, it uses linear programming to solve for the actual correction amount of the regional control deviation allocated to each provincial power grid; and distributes the actual correction amount of the regional control deviation to each provincial dispatch AGC system to calculate the corrected regional control deviation.

[0052] Real-time control module: Used by provincial dispatch AGC systems to control the active power of frequency-regulating units under their control based on the corrected regional control deviation.

[0053] A third aspect of the present invention provides a grid-province AGC collaborative optimization control device considering grid security constraints, comprising a processor and a memory, wherein the memory stores computer instructions, and the processor is used to execute the computer instructions stored in the memory. When the computer instructions are executed by the processor, the device implements the steps of the grid-province AGC collaborative optimization control method considering grid security constraints described in the first aspect of the present invention.

[0054] A fourth aspect of the present invention provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the steps of the grid-province AGC collaborative optimization control method considering grid security constraints as described in the first aspect of the present invention.

[0055] The beneficial effects of this invention are that, compared with existing technologies, it addresses the difficulty of adapting the independent control mode of traditional provincial power grids to the frequency regulation needs brought about by large-scale inter-regional power mutual assistance and the uncertainty of new energy sources. It proposes a grid-province AGC collaborative optimization control method considering grid security constraints. This method preprocesses the original regional control deviation (ACE) data of each control area through grid dispatching and constructs a collaborative optimization control model with ACE correction as the decision variable. The model comprehensively considers grid security constraints such as tie-line power limits, and uses linear programming to solve for an ACE correction allocation scheme that meets the overall grid coordination requirements. This achieves coordinated mutual assistance and control of frequency regulation resources at both the grid and provincial levels while ensuring the safe operation of the power grid. This method breaks down the physical barriers of traditional control intervals and solves the shortcomings of existing coordinated control methods in terms of consistency of regulation direction, dynamic adaptability, and daily operational continuity. It provides an effective way for the complementary utilization of inter-regional frequency regulation resources in new power systems, guides the formulation of grid-province collaborative AGC strategies considering grid security constraints, and provides technical support for improving the frequency control performance and operational safety of large power grids. The method proposed in this invention is not limited to a single simulation software, but is applicable to all graphical modeling and simulation software. Attached Figure Description

[0056] Figure 1 This is a flowchart illustrating a grid-province AGC collaborative optimization control method considering grid security constraints, as disclosed in an embodiment of the present invention.

[0057] Figure 2 This is a schematic diagram of the structure of a grid-province AGC collaborative optimization control system that considers grid security constraints, as disclosed in an embodiment of the present invention.

[0058] Figure 3 This is a schematic diagram of the structure of a grid-province AGC collaborative optimization control device that takes into account grid security constraints, as disclosed in an embodiment of the present invention. Detailed Implementation

[0059] To make the objectives, technical solutions, and advantages of this invention clearer, the technical solutions of this invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of this invention. The embodiments described in this application are merely some embodiments of this invention, and not all embodiments. Based on the spirit of this invention, all other embodiments obtained by those skilled in the art without creative effort are within the protection scope of this invention.

[0060] Example 1:

[0061] like Figure 1 As shown, Embodiment 1 of the present invention discloses a grid-province AGC collaborative optimization control method considering grid security constraints. Wherein, Figure 1The described grid-province AGC collaborative optimization control method considering grid security constraints is applicable to power systems, such as for the operation control of high-proportion renewable energy grid integration, etc., and the embodiments of this invention are not limited thereto. Figure 1 As shown, the grid-province AGC collaborative optimization control method considering grid security constraints may include the following operations:

[0062] S1. Obtain the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids, the planned active power value and the tie line power limit through the AGC system of each provincial dispatch center. Calculate the original regional control deviation of the corresponding provincial power grid based on the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids and the planned active power value, and upload the original regional control deviation to the grid dispatch AGC system.

[0063] The specific implementation process of step S1 is as follows:

[0064] S1.1, For provincial power grids i ( i =1…… N The provincial AGC system monitored its actual operating frequency as follows: f i and provincial power grid j ( j =1…… N, j ≠ i The actual power of the tie line between them is P ij Provincial power grid i Original area control deviation ACE i The calculation method is as follows:

[0065]

[0066] in, f i For provincial power grid i The frequency; B i This is the frequency deviation coefficient. It should be noted that for each provincial power grid, the negative product of the difference between the corresponding frequency and the rated frequency and the frequency deviation coefficient, plus the difference between the actual active power value and the planned active power value of all other provincial power grids connected to the corresponding provincial power grid via tie lines, yields the original regional control deviation of the corresponding provincial power grid. In this embodiment, the multiplication by 10 in the above formula is necessary for unit conversion. B i The unit is MW / 0.1Hz; f n The rated frequency is expressed in Hz. P ij For provincial power gridi and j The actual active power value of the connecting lines between them; P ijn For provincial power grid i and j The planned active power value of the interconnection line between the two power grids, in MW, is as follows: i and j When there is no connecting line between them, P ij = P ijn =0; N This refers to the number of provincial power grids.

[0067] S1.2, Interconnection and communication between provincial dispatch AGC and grid dispatch AGC, when the provincial power grid i The provincial AGC system completed the original regional control deviation. ACE i After calculation, the original area control deviation is... ACE i The data is uploaded to the provincial dispatch AGC system, which monitors the raw regional control deviation uploaded in real time. ACE i .

[0068] S2. In the grid dispatch AGC system, based on the original regional control deviation of each provincial power grid and the sum of the original regional control deviations of all provincial power grids, the target value of the regional control deviation correction amount to be issued to each provincial dispatch AGC system is calculated by judging the positive and negative relationships and proportional allocation.

[0069] The specific implementation process of step S2 is as follows:

[0070] S2.1 When there are cases where the positive and negative signs of the original regional control deviations of each provincial power grid are opposite, the target value of the ACE correction amount of each region is calculated by proportional allocation based on the original regional control deviations of each provincial power grid with different positive and negative signs and the sum of the original regional control deviations of all provincial power grids; when the positive and negative signs of the original regional control deviations of all provincial power grids are the same, the target value of the correction amount of all regional control deviations is 0.

[0071] S2.2 When the original regional control deviation data uploaded by the provincial power grid dispatch AGC system of each province have opposite signs, the original regional control deviations of all provincial power grids are added together to calculate the total original regional control deviation of all provincial power grids. ACE total :

[0072]

[0073] remember Provincial power grids have k One, for provincial power grids i ( i =1,…… k ),if Then its regional control deviation ACE i The target value of the correction amount Δ ACE i_obj for:

[0074]

[0075] remember Provincial power grids have N-k If the total original area control deviation is one, For the original area control deviation For the provincial power grids, the original regional control deviations of each provincial power grid are sorted from smallest to largest. For the th... i ( i = k +1,…… N -1) Regional control deviation of provincial power grids ACE i The target value of the correction amount Δ ACE i_obj for:

[0076]

[0077]

[0078] in, ACE n-total This represents the sum of the original regional control deviations of the provincial power grid with negative signs. ACE p-total This represents the sum of the original regional control deviations of the provincial power grid with positive signs. For the... k +1 to N -1 provincial power grid, if its Δ ACE i If the calculation result is a decimal, then Δ ACE i Rounding to the nearest whole number, the first... N Δ of provincial power grids ACE m_obj for:

[0079]

[0080] for of N-k For each provincial power grid, if the total original regional control deviation is... Then for the original area control deviation For each provincial power grid, the original regional control deviations of the provincial power grids are sorted from largest to smallest. For the th... i ( i = k +1,…… N -1) Regional control deviation of provincial power grids ACE i The target value of the correction amount Δ ACE i_obj for:

[0081]

[0082] For the K+1 to N-1 provincial power grids, if Δ ACE i_obj If the calculation result is a decimal, then Δ ACE i_obj Rounding to the nearest whole number, the first... N The target value Δ for the regional control deviation correction of a provincial power grid ACE N_obj for:

[0083]

[0084] S3. In the grid dispatch AGC system, an objective function is constructed based on the target value of the regional control deviation correction and the corrected regional control deviation. At the same time, a constraint function considering grid security constraints is constructed based on the tie line power limit, thereby establishing a grid-province AGC collaborative optimization control model.

[0085] The specific implementation process of step S3 is as follows:

[0086] S3.1 Objective function of the network-province AGC collaborative optimization control model f It consists of two sub-objective functions with different priorities. f 1. f 2. Composition, the first sub-objective function f 1 is the sum of the actual correction amount of the control deviation in each region and the absolute value of the corresponding target value deviation;

[0087]

[0088] Where, Δ ACE i For provincial power grid i The actual correction amount of ACE.

[0089] Second sub-objective function f 2. To minimize the sum of the absolute values ​​of the corrected area control deviations, the corrected area control deviation is the original area control deviation plus the corresponding actual correction amount; the corrected area control deviation is:

[0090]

[0091] objective function f 2 is:

[0092]

[0093] The priority of the objective function is f 1 has a higher priority than f 2. Priority, objective function of the provincial AGC collaborative optimization control model f for:

[0094]

[0095] S3.2, First Constraint c 1 represents the sum of the actual corrections for all area control deviations and the ACE corrections, which is 0.

[0096]

[0097] Second constraint c 2. For each tie line, the current value of the tie line's apparent power, plus the product of all corrected area control deviations and the corresponding power transmission distribution factor, must be greater than or equal to the maximum negative power of the tie line and less than or equal to the maximum positive power of the tie line. This constraint considers the power safety limits for inter-area interconnection lines, and the formula is:

[0098]

[0099] in, , , The lines are respectively l The current value of apparent power, the maximum values ​​of negative and positive power, and the tie line power limit, which includes the maximum value of negative tie line power and the maximum value of positive tie line power.

[0100] Let be the power transfer distribution factor, the th i The unit power variation of provincial power grids on interconnecting lines l The power change caused by the above can be expressed as:

[0101]

[0102] in, For provincial power grid i Change in active power For connecting lines l Changes in active power.

[0103] Third constraintc 3. To connect with the provincial power grid i The sum of the apparent power of all interconnected lines equals that of the provincial power grid. i Net power injection, ignoring network losses:

[0104]

[0105] in, M In order to connect with the provincial power grid i The total number of connected communication lines. In order to connect with the provincial power grid i Connecting lines l Apparent power For provincial power grid i Total power generation within, For provincial power grid i Total load power within.

[0106] constraint functions c for:

[0107]

[0108] The collaborative optimization control model for AGC in the province is as follows:

[0109]

[0110] S4. Based on the constructed provincial AGC collaborative optimization control model, the actual correction amount of the regional control deviation allocated to each provincial power grid is solved by linear programming. The actual correction amount of the regional control deviation is then sent to each provincial dispatch AGC system to calculate the corrected regional control deviation. Each provincial dispatch AGC system performs active power control on its frequency regulation units based on the corrected regional control deviation.

[0111] The specific implementation process of step S4 is as follows:

[0112] S4.1, The first step is to define the objective function. f The formula in step 1 is transformed into a linear function, which is then solved using a linear programming solver.

[0113] If the first step yields a unique solution, the second step is discontinued, and the actual correction values ​​for the regional control deviations of each provincial power grid, obtained in the first step, are distributed to the respective provincial dispatch AGC systems. If the first step yields two or more solutions, the second step continues, and the objective function is... f Formula 2 is transformed into a linear function, and based on the objective function... f The optimal value of 1 is given an additional constraint, which is solved using a linear programming solver.

[0114] If a unique solution is obtained in the second step, the actual correction amount of the regional control deviation of each provincial power grid obtained in the second step is sent to the provincial dispatch AGC system. If two or more solutions appear in the second step, a set of actual correction amounts of the regional control deviation of each provincial power grid is selected from the optimal solution set of the second step and sent to the provincial dispatch AGC system.

[0115] S4.2, For provincial power grids i Define two nonnegative variables , ,make:

[0116]

[0117] in, , Provincial power grids i The first and second non-negative variables;

[0118] but:

[0119]

[0120] objective function f 1. Transform into a linear function:

[0121]

[0122] This transforms the nonlinear absolute value objective into a linear objective function and linear constraints, which can then be solved using a linear programming solver.

[0123] S4.3 Objective Function f 2 is also a nonlinear function, and therefore needs to be converted into a linear function for solving. For provincial power grids... i Define two nonnegative variables , ,make:

[0124]

[0125] in, , Provincial power grids i The first and second non-negative variables;

[0126] but:

[0127]

[0128] objective function f 2. Transform into a linear function:

[0129]

[0130] To ensure that the solution in the second step is one of the two or more solutions from the first step, an additional constraint needs to be added to the constraints from the first step. This constraint is derived from the objective function obtained in the first step. f The optimal value is denoted as The additional constraints are:

[0131]

[0132] Solving based on a linear programming solver f Using a linear objective function of 2, the actual correction amount of the regional control deviation of each provincial power grid is obtained. The optimal solution is then determined. The actual correction amount of the regional control deviation of each provincial power grid is sent to the provincial dispatch AGC system, and each provincial dispatch AGC system performs active power control on the frequency regulation units it regulates based on the corrected regional control deviation.

[0133] This invention constructs a two-level (grid-province) ACE data interaction and collaborative optimization control model. Based on grid security constraints such as tie-line power limits, it achieves coordinated and mutually supportive cross-regional frequency regulation resources, ensuring the safe and stable control of the large power grid frequency. This invention provides methodological support for grid-province collaborative AGC control in new power systems and is beneficial for guiding the formulation of cross-regional AGC collaborative optimization strategies that consider grid security constraints.

[0134] Example 2:

[0135] like Figure 2 As shown, Embodiment 2 of the present invention discloses a grid-province AGC collaborative optimization control system considering grid security constraints. This system can realize coordinated operation control of grid-province AGC, and includes: a data acquisition module, a data preprocessing module, a model building module, a model solving module, and a real-time control module, specifically:

[0136] Data acquisition module: used to obtain the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids, the planned active power value and the tie line power limit through the AGC system of each provincial dispatch center; based on the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids and the planned active power value, calculate the original regional control deviation of the corresponding provincial power grid, and upload the original regional control deviation to the grid dispatch AGC system;

[0137] Data preprocessing module: In the grid dispatch AGC system, based on the original regional control deviation of each provincial power grid and the sum of the original regional control deviations of all provincial power grids, the target value of the regional control deviation correction amount to be sent to each provincial dispatch AGC system is calculated by judging the positive and negative relationship and proportional allocation.

[0138] Model building module: used to construct an objective function based on the target value of the regional control deviation correction and the corrected regional control deviation, and at the same time to construct a constraint function based on the tie line power limit that takes into account the power grid safety constraints, thereby establishing a grid-province AGC collaborative optimization control model;

[0139] Model Solving Module: Based on the constructed provincial AGC collaborative optimization control model, it uses linear programming to solve for the actual correction amount of the regional control deviation allocated to each provincial power grid; and distributes the actual correction amount of the regional control deviation to each provincial dispatch AGC system to calculate the corrected regional control deviation.

[0140] Real-time control module: Used by provincial dispatch AGC systems to control the active power of frequency-regulating units under their control based on the corrected regional control deviation.

[0141] Example 3:

[0142] like Figure 3 As shown, an embodiment of the present invention discloses a grid-province AGC collaborative optimization control device that considers grid security constraints. Wherein, Figure 3 The described equipment can be applied to power systems, such as for the operation and control of high-proportion renewable energy grid access, and the embodiments of the present invention are not limited thereto.

[0143] like Figure 3 As shown, the device may include a processor and a memory, the memory storing computer instructions, and the processor executing the computer instructions stored in the memory. When the computer instructions are executed by the processor, the device implements the steps of the method described in the above embodiments and achieves the same technical effect as the above method.

[0144] The memory may include computer system readable media in the form of volatile memory, such as random access memory (RAM) and / or cache memory. The device may further include other removable / non-removable, volatile / non-volatile computer system storage media. By way of example only, the memory may be used to read and write non-removable, non-volatile magnetic media (commonly referred to as a "hard disk drive"). A program / utility having a set (at least one) of program modules may be stored in, for example, memory. Such program modules include, but are not limited to, an operating system, one or more application programs, other program modules, and program data. Each or some combination of these examples may include an implementation of a network environment. The program modules typically perform the functions and / or methods described in the embodiments of the present invention.

[0145] The processor executes various functional applications and data processing by running programs stored in memory, such as the method provided in Embodiment 1 of the present invention.

[0146] Example 4:

[0147] Embodiment 4 of the present invention also provides a computer-readable storage medium storing a computer program thereon. When the program is executed by a processor, it implements the steps of the method described in the above embodiments and achieves the same technical effect as the above method.

[0148] Computer-readable storage media can be tangible devices capable of holding and storing instructions for use by an instruction execution device. Computer-readable storage media can be, for example—but not limited to—electrical storage devices, magnetic storage devices, optical storage devices, electromagnetic storage devices, semiconductor storage devices, or any suitable combination of the foregoing. More specific examples (a non-exhaustive list) of computer-readable storage media include: portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), static random access memory (SRAM), portable compact disc read-only memory (CD-ROM), digital multifunction disc (DVD), memory sticks, floppy disks, mechanical encoding devices, such as punch cards or recessed protrusions storing instructions thereon, and any suitable combination of the foregoing. The computer-readable storage media used herein are not to be construed as transient signals themselves, such as radio waves or other freely propagating electromagnetic waves, electromagnetic waves propagating through waveguides or other transmission media (e.g., light pulses through fiber optic cables), or electrical signals transmitted through wires.

[0149] The computer-readable program instructions described herein can be downloaded from computer-readable storage media to various computing / processing devices, or downloaded via a network, such as the Internet, local area network, wide area network, and / or wireless network, to an external computer or external storage device. The network may include copper transmission cables, fiber optic transmission, wireless transmission, routers, firewalls, switches, gateway computers, and / or edge servers. A network adapter card or network interface in each computing / processing device receives the computer-readable program instructions from the network and forwards them to the computer-readable storage media in the respective computing / processing device.

[0150] Computer program instructions used to perform the operations of this disclosure may be assembly instructions, instruction set architecture (ISA) instructions, machine instructions, machine-dependent instructions, microcode, firmware instructions, status setting data, or source code or object code written in any combination of one or more programming languages, including object-oriented programming languages ​​such as Smalltalk, C++, etc., and conventional procedural programming languages ​​such as the "C" language or similar programming languages. The computer-readable program instructions may execute entirely on the user's computer, partially on the user's computer, as a standalone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving a remote computer, the remote computer may be connected to the user's computer via any type of network—including a local area network (LAN) or a wide area network (WAN)—or may be connected to an external computer (e.g., via the Internet using an Internet service provider). In some embodiments, electronic circuitry, such as programmable logic circuitry, field-programmable gate arrays (FPGAs), or programmable logic arrays (PLAs), is personalized by utilizing the status information of the computer-readable program instructions to implement various aspects of this disclosure.

[0151] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and not to limit it. Although the present invention has been described in detail with reference to the above embodiments, those skilled in the art should understand that modifications or equivalent substitutions can still be made to the specific implementation of the present invention. Any modifications or equivalent substitutions that do not depart from the spirit and scope of the present invention should be covered within the protection scope of the claims of the present invention.

Claims

1. A grid-province AGC collaborative optimization control method considering grid security constraints, characterized in that, include: The frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids, the planned active power value and the tie line power limit are obtained through the AGC system of each province. Based on the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids and the planned active power value, the original regional control deviation of the corresponding provincial power grid is calculated and uploaded to the grid dispatch AGC system. In the grid dispatch AGC system, based on the original regional control deviation of each provincial power grid and the sum of the original regional control deviations of all provincial power grids, the target value of the regional control deviation correction amount is calculated and distributed to each provincial dispatch AGC system through positive and negative relationship judgment and proportional allocation. An objective function is constructed based on the target value of the regional control deviation correction and the corrected regional control deviation. At the same time, a constraint function considering grid security constraints is constructed based on the tie-line power limit, thereby establishing a grid-province AGC collaborative optimization control model. Based on the constructed grid-province AGC collaborative optimization control model, the actual correction amount of the regional control deviation allocated to each provincial power grid is solved by linear programming. The actual correction amount of the regional control deviation is then sent to each provincial dispatch AGC system to calculate the corrected regional control deviation. Each provincial dispatch AGC system performs active power control on its frequency regulation units based on the corrected regional control deviation.

2. The grid-province AGC collaborative optimization control method considering grid security constraints according to claim 1, characterized in that: The original regional control deviation of the corresponding provincial power grid is calculated based on the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids, and the planned active power value. Specifically: For each provincial power grid, the negative product of the difference between the corresponding frequency and the rated frequency and the frequency deviation coefficient, plus the difference between the actual active power value and the planned active power value of all other provincial power grids connected to the corresponding provincial power grid via tie lines, yields the original regional control deviation of the corresponding provincial power grid.

3. The grid-province AGC collaborative optimization control method considering grid security constraints according to claim 1, characterized in that: The target value of the regional control deviation correction amount, calculated and distributed to each provincial AGC system based on the positive and negative relationship and proportional allocation, is as follows: When the original regional control deviations of each provincial power grid have opposite positive and negative signs, the target value of the ACE correction for each region is calculated by proportional allocation based on the original regional control deviations of each provincial power grid with different positive and negative signs and the sum of the original regional control deviations of all provincial power grids; when the positive and negative signs of the original regional control deviations of all provincial power grids are the same, the target value of the correction for all regional control deviations is 0.

4. The grid-province AGC collaborative optimization control method considering grid security constraints according to claim 3, characterized in that: When the original regional control deviations of each provincial power grid contain cases where the positive and negative signs are opposite, the target value of the regional control deviation correction is calculated by proportional allocation, specifically as follows: First, calculate the sum of the original regional control deviations of all provincial power grids; For each provincial power grid, if the original regional control deviation of the provincial power grid is of opposite sign to the sum of the original regional control deviations of all provincial power grids, then the target value of the regional control deviation correction for that provincial power grid is the original regional control deviation of the provincial power grid with a negative sign; the number of provincial power grids corresponding to this opposite sign is... k ; Otherwise, if the original regional control deviation of the provincial power grid and the sum of the original regional control deviations of all provincial power grids have the same sign, the target value of the regional control deviation correction shall be calculated according to the proportional allocation principle.

5. The grid-province AGC collaborative optimization control method considering grid security constraints according to claim 4, characterized in that: If the original regional control deviation of a provincial power grid and the sum of the original regional control deviations of all provincial power grids have the same sign, then the target value of the regional control deviation correction is calculated according to the proportional allocation principle, specifically as follows: If the original regional control deviations of the corresponding provincial power grids and the sum of the original regional control deviations of all provincial power grids are both positive, then the original regional control deviations of all provincial power grids are sorted in ascending order. Add up the positive deviations from the original regional control deviations of all provincial power grids to get the total positive deviations; then add up the negative deviations to get the total negative deviations. For the k +1 to the N -1 provincial power grid, N For the total number of provincial power grids, the target value for the regional control deviation correction of the corresponding provincial power grid is the product of the proportion of the original regional control deviation of the corresponding provincial power grid in the total positive deviation and the total negative deviation; if the calculated number of... k +1 to the N If the target value of the regional control deviation correction for a provincial power grid is not an integer, it will be rounded to the nearest integer. No. N The target value for the regional control deviation correction of a provincial power grid is the sum of all original regional control deviations with negative signs minus the first... k +1 to the N -1 The sum of the target values ​​of the regional control deviation correction for a provincial power grid; If the original regional control deviations of the corresponding provincial power grids and the sum of the original regional control deviations of all provincial power grids are both negative, then the original regional control deviations of all provincial power grids are sorted from largest to smallest. For the th k +1 to the N -1 provincial power grids, the target value of the regional control deviation correction for the corresponding provincial power grid is the product of the proportion of the original regional control deviation in the total negative deviations and the total positive deviations; if the calculated number of... k +1 to the N If the target value of the regional control deviation correction for a provincial power grid is not an integer, it will be rounded to the nearest integer. No. N The target value for the regional control deviation correction of a provincial power grid is the sum of all original regional control deviations with positive signs minus the first... k +1 to the N -1 is the sum of the target values ​​of the regional control deviation correction for a provincial power grid.

6. The grid-province AGC collaborative optimization control method considering grid security constraints according to claim 1, characterized in that: The objective function is constructed based on the target value of the area control deviation correction and the corrected area control deviation, as follows: Objective function of the collaborative optimization control model of AGC in the network province f It consists of two sub-objective functions with different priorities. f 1. f 2. Composition, the first sub-objective function f 1 is the sum of the actual correction amount of the control deviation in each region and the absolute value of the corresponding target value deviation; Second sub-objective function f 2. To minimize the sum of the absolute values ​​of each corrected regional control deviation, the corrected regional control deviation is the original regional control deviation plus the actual correction amount of the corresponding regional control deviation.

7. The grid-province AGC collaborative optimization control method considering grid security constraints according to claim 1, characterized in that: The constraint function, which takes into account grid security constraints, is constructed based on tie-line power limits. Specifically: The tie line power limits include the maximum power of the tie line in the negative direction and the maximum power of the tie line in the positive direction. The first constraint is: the sum of the actual corrections for all area control deviations is 0. The second constraint is: for each tie line, the current value of the tie line apparent power plus the product of all corrected area control deviations and the corresponding power transmission distribution factor, the sum of which is greater than or equal to the maximum power of the tie line negative power and less than or equal to the maximum power of the tie line positive power. The power transmission distribution factor is the power change caused by the change in unit active power of the provincial power grid corresponding to the corrected regional control deviation on the corresponding tie line. The third constraint is that the sum of the apparent power of all tie lines connected to the provincial power grid is equal to the net power injection of the corresponding provincial power grid.

8. The grid-province AGC collaborative optimization control method considering grid security constraints according to claim 1, characterized in that: Based on the constructed provincial-level AGC collaborative optimization control model, the actual correction amount of the regional control deviation allocated to each provincial power grid is solved using the linear programming method, specifically: The first step is to define the objective function. f The formula in step 1 is transformed into a linear function, which is then solved using a linear programming solver. If the first step yields a unique solution, the second step is discontinued, and the actual correction values ​​for the regional control deviations of each provincial power grid, obtained in the first step, are distributed to the respective provincial dispatch AGC systems. If the first step yields two or more solutions, the second step continues, and the objective function is... f Formula 2 is transformed into a linear function, and based on the objective function... f The optimal value of 1 is given an additional constraint, which is solved using a linear programming solver. If a unique solution is obtained in the second step, the actual correction amount of the regional control deviation of each provincial power grid obtained in the second step is sent to the provincial dispatch AGC system. If two or more solutions appear in the second step, a set of actual correction amounts of the regional control deviation of each provincial power grid is selected from the optimal solution set of the second step and sent to the provincial dispatch AGC system.

9. The grid-province AGC collaborative optimization control method considering grid security constraints according to claim 8, characterized in that: Objective function f The formula in step 1 is transformed into a linear function, which is then solved using a linear programming solver, specifically: For each provincial power grid, two non-negative variables are defined as the first non-negative variable and the second non-negative variable. Let the actual correction amount of the regional control deviation of the corresponding provincial power grid minus the target value of the corresponding regional control deviation correction amount be equal to the first non-negative variable minus the second non-negative variable. objective function f The formula in step 1 is transformed into a linear function that minimizes the sum of the first and second non-negative variables corresponding to all provincial power grids.

10. The grid-province AGC collaborative optimization control method considering grid security constraints according to claim 8, characterized in that: Objective function f Formula 2 is transformed into a linear function, and based on the objective function... f The optimal value of 1 is subject to an additional constraint, specifically: For each provincial power grid, two non-negative variables are defined as the third non-negative variable and the fourth non-negative variable. The corrected regional control deviation of the corresponding provincial power grid is equal to the third non-negative variable minus the fourth non-negative variable. objective function f Formula 2 can be transformed into a linear function that minimizes the sum of the third and fourth non-negative variables corresponding to all provincial power grids; The added constraint is that the sum of the difference between the actual correction amount of the regional control deviation of all provincial power grids and the target value of the corresponding regional control deviation correction amount is less than or equal to the optimal value of the objective function.

11. A grid-province AGC collaborative optimization control system considering grid security constraints, based on the method of any one of claims 1-10, comprising: The data acquisition module, data preprocessing module, model building module, model solving module, and real-time control module are characterized by: Data acquisition module: used to obtain the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids, the planned active power value and the tie line power limit through the AGC system of each provincial dispatch center; based on the frequency of the corresponding provincial power grid, the actual active power value of the tie line with other provincial power grids and the planned active power value, calculate the original regional control deviation of the corresponding provincial power grid, and upload the original regional control deviation to the grid dispatch AGC system; Data preprocessing module: In the grid dispatch AGC system, based on the original regional control deviation of each provincial power grid and the sum of the original regional control deviations of all provincial power grids, the target value of the regional control deviation correction amount to be sent to each provincial dispatch AGC system is calculated by judging the positive and negative relationship and proportional allocation. Model building module: used to construct an objective function based on the target value of the regional control deviation correction and the corrected regional control deviation, and at the same time to construct a constraint function based on the tie line power limit that takes into account the power grid safety constraints, thereby establishing a grid-province AGC collaborative optimization control model; Model Solving Module: Based on the constructed provincial AGC collaborative optimization control model, it uses linear programming to solve for the actual correction amount of the regional control deviation allocated to each provincial power grid; and distributes the actual correction amount of the regional control deviation to each provincial dispatch AGC system to calculate the corrected regional control deviation. Real-time control module: Used by provincial dispatch AGC systems to control the active power of frequency-regulating units under their control based on the corrected regional control deviation.

12. A grid-province AGC collaborative optimization control device considering grid security constraints, characterized in that, The device includes a processor and a memory, wherein the memory stores computer instructions, and the processor executes the computer instructions stored in the memory. When the computer instructions are executed by the processor, the device implements the steps of the grid-province AGC collaborative optimization control method considering grid security constraints as described in any one of claims 1 to 10.

13. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that, when executed by a processor, implements the steps of the grid-province AGC collaborative optimization control method considering grid security constraints as described in any one of claims 1 to 10.

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