Automatic scheduling operation ticket forming method and system for regional linkage of smart power grid

Abstract

The invention discloses an automatic scheduling operation ticket forming method and system for regional linkage of a smart power grid, and relates to the technical field of power grid scheduling, and the method comprises the following steps: obtaining a scheduling instruction and a real-time operation condition of the power grid, generating an initial operation ticket containing cross-regional communication operation, and generating a scheduling operation ticket; establishing a sensitivity matrix of the electrical quantity of the tie line to the control parameters of the adjustable equipment; enabling the switching action of the cross-region connection operation to be equivalent to an impedance change track, extracting a steady-state electrical quantity extreme value, and generating a control parameter compensation value in combination with a preset safety threshold value and a sensitivity matrix; according to the error interval of the equivalent parameters of the opposite-end power grid of the tie line, calculating a transient current envelope line at the cross-region connection moment, and solving a tie line switching-on phase angle meeting a preset protection constant value constraint; and integrating the control parameter compensation value and the closing phase angle to the initial operation ticket to generate a final operation ticket. The method is used for solving the problems that in the prior art, the out-of-limit risk is difficult to continuously evaluate, quantitative control cannot be formed, and transient switching-on reliability is insufficient.

Description

Technical Field

[0001] This invention relates to the field of power grid dispatching technology, and more specifically, to a method and system for automatically generating dispatching operation tickets for regional linkage in smart grids. Background Technology

[0002] As smart grids become increasingly interconnected across regions, the automatic generation of dispatch operation tickets plays a crucial role in the complex operation and management of power grids, such as cross-regional connection and loop unconnection.

[0003] For example, invention application CN120675297A discloses an operation ticket safety verification and error prevention operating system. This system generates operation tickets by acquiring real-time power grid data and combining it with topology reasoning. Power flow transfer analysis and static differential pressure verification are performed before operation to achieve error prevention and control. Another example is invention application CN117787890A, which discloses a distribution network intelligent error prevention operation ticket system. This system analyzes the impact of operations on the power grid state by simulating changes in the state of operating equipment and provides reminders for operations such as opening and closing loops in the power grid.

[0004] However, the aforementioned existing technologies still have the following technical problems in practical applications: 1. In power grid topology changes such as inter-regional interconnection, it is difficult to continuously assess the electrical quantity fluctuation boundaries throughout the entire operation process, and steady-state over-limit or local overload phenomena are prone to occur when the operation is carried out according to the ticket. 2. The existing over-limit warning mechanism is difficult to directly translate into quantitative control instructions for adjustable equipment. It usually requires repeated manual calculation and adjustment of invoices, which affects the efficiency of invoice processing and operational safety. 3. Transient inrush currents can easily be generated during cross-regional closing, causing protection devices to operate. Furthermore, when there are fluctuations in the parameters of the grid at the other end, conventional safety assessment results often deviate from the actual operating conditions, making it difficult to guarantee the reliability of the connection operation.

[0005] Therefore, there is an urgent need for an automatic scheduling operation ticket generation method and system that integrates extreme value assessment throughout the entire process, quantitative equipment compensation, and transient closing reliability under parameter fluctuations. Summary of the Invention

[0006] To overcome the aforementioned deficiencies of the prior art, embodiments of the present invention provide an automatic ticketing method and system for dispatching operation tickets in smart grid regional linkage. By equating cross-regional connection operations to impedance evolution trajectories and combining sensitivity analysis and error propagation analysis, the present invention addresses the problems of difficulty in continuously assessing over-limit risks, inability to form quantitative control, and insufficient reliability of transient closing in the prior art.

[0007] To achieve the above objectives, the present invention provides the following technical solution: A method for automatically generating dispatch operation tickets for regional linkage in a smart grid includes the following steps: Obtain dispatch instructions and real-time power grid operating conditions, generate initial operation tickets including cross-regional interconnection operations, and establish a sensitivity matrix of tie line electrical quantities to adjustable equipment control parameters; The switching action of the cross-regional connection operation is equivalent to an impedance change trajectory, and the extreme values ​​of steady-state electrical quantities that evolve with the trajectory are extracted. The control parameter compensation values ​​are generated by combining the preset safety threshold with the sensitivity matrix. Based on the error range of the equivalent parameters of the grid at the other end of the tie line, the transient current envelope at the moment of cross-regional connection is calculated through error propagation, and the tie line closing phase angle that satisfies the preset protection setting constraints is solved. The control parameter compensation value and the closing phase angle are integrated into the initial operation ticket to generate the final operation ticket.

[0008] In a preferred embodiment, establishing the sensitivity matrix of tie-line electrical quantities to adjustable device control parameters includes: solving for the current node state variables and node state response feature matrices based on a preset balance mapping relationship between node injected power and node state variables; establishing a first partial derivative matrix of tie-line electrical quantities relative to the current node state variables, and a second partial derivative matrix of the balance mapping relationship relative to the adjustable device control parameters; and performing a cascade operation on the feature matrix, the first partial derivative matrix, and the second partial derivative matrix to obtain the sensitivity matrix.

[0009] In a preferred embodiment, the equivalent impedance change trajectory includes: introducing a continuous homotopy parameter, configuring the admittance of the branch corresponding to the cross-regional connection operation as a correlation term that changes with the homotopy parameter, so that the branch admittance transitions continuously between the open and closed states, thereby forming the impedance change trajectory.

[0010] In a preferred embodiment, the step of extracting the extreme values ​​of steady-state electrical quantities that evolve with the trajectory includes: substituting the correlation term into the balance mapping relationship, and obtaining a continuous power flow solution sequence of the current node state variable evolving with the impedance change trajectory by incrementing the continuous homotopy parameter; and extracting the voltage amplitude and current amplitude with limit deviations relative to the rated reference value from the solution sequence as the extreme values ​​of steady-state electrical quantities.

[0011] In a preferred embodiment, generating control parameter compensation values ​​includes: constructing an electrical quantity over-limit vector based on the deviation between the steady-state electrical quantity extreme value and a preset safety threshold; using the sensitivity matrix, constructing an inverse mapping relationship between the tie-line electrical quantity and the control parameters, and mapping the over-limit vector to the adjustment increment of each control parameter to obtain control parameter compensation values.

[0012] In a preferred embodiment, the calculation of the transient current envelope at the moment of cross-regional connection includes: converting the error range of the equivalent parameters of the peer power grid into an affine form containing the center value and noise term; establishing an electromagnetic transient constraint relationship between the transient current of the tie line and the equivalent parameters of the affine form; traversing the candidate closing phase angles, and after obtaining the upper and lower current limits for each time step by performing affine deduction based on the electromagnetic transient constraint relationship, generating the transient current envelope corresponding to each candidate closing phase angle.

[0013] In a preferred embodiment, generating the transient current envelope corresponding to each candidate closing phase angle includes: substituting the candidate closing phase angle as an initial phase condition into the electromagnetic transient constraint relationship, performing a time-step affine derivation to obtain a transient current affine solution; performing algebraic operations on the center value and the weight of each noise term of the affine solution to obtain the upper and lower current limits corresponding to each time step; and connecting the upper and lower current limits in time sequence to generate the transient current envelope.

[0014] In a preferred embodiment, the step of solving the tie-line closing phase angle that satisfies the preset protection setting constraints includes: extracting the peak value of the transient current envelope corresponding to each candidate closing phase angle, and selecting a set of continuous candidate closing phase angles whose peak values ​​satisfy the preset protection setting constraints as the phase safety interval; and selecting the tie-line closing phase angle from the phase safety interval based on a preset safety assessment strategy.

[0015] In a preferred embodiment, generating the final operation ticket includes: converting the control parameter compensation value into a corresponding equipment adjustment instruction and inserting it as a preliminary step before the closing instruction for cross-zone connection operation in the initial operation ticket; configuring the tie line closing phase angle as a trigger setting parameter in the execution attribute of the closing instruction; and performing logical verification and format encapsulation on the initial operation ticket that has completed instruction integration and attribute configuration to obtain the final operation ticket.

[0016] An automatic ticket generation system for implementing any of the methods described herein includes the following modules: The initial ticket generation module is used to acquire dispatch instructions and real-time power grid operating conditions, generate initial operation tickets including cross-regional connection operations, and establish a sensitivity matrix of tie line electrical quantities to adjustable equipment control parameters. The steady-state compensation module is used to equate the switching action of the cross-regional connection operation to an impedance change trajectory, extract the extreme values ​​of steady-state electrical quantities that evolve with the trajectory, and generate control parameter compensation values ​​by combining a preset safety threshold with the sensitivity matrix. The transient phase-finding module is used to calculate the transient current envelope at the moment of cross-regional connection based on the error range of the equivalent parameters of the grid at the other end of the tie line through error propagation, and to solve the tie line closing phase angle that satisfies the preset protection setting constraints. An integrated ticketing module is used to integrate the control parameter compensation value and the closing phase angle into the initial operation ticket to generate the final operation ticket.

[0017] The technical effects and advantages of the present invention regarding the automatic ticket generation method and system for regional linkage dispatching operations in smart grids are as follows: 1. This invention equates the switching action of cross-regional connection operation to a continuous impedance change trajectory, and uses a sensitivity matrix to map the extreme values ​​of electrical quantities that evolve with the trajectory to quantitative compensation values ​​of adjustable equipment. It establishes a dynamic monitoring and predictive correction mechanism for the entire switching action process, effectively solving the problem of blind spots in the perception of steady-state over-limit during the transition period by traditional discrete section verification methods, and improving the steady-state safety adaptability of scheduling operation tickets under topology change conditions.

[0018] 2. This invention introduces an affine form representing the error of the equivalent parameters of the peer power grid to perform error propagation deduction, generates a transient current envelope, and uses this as a constraint to determine the closing phase angle of the tie line. It constructs a transient impact defense system that considers parameter uncertainty, reduces the risk of transient current exceeding limits and protection malfunction caused by cross-regional model distortion or fluctuations in operating data, and enhances the execution stability of the scheduling ticketing scheme and the intrinsic safety level of the power grid in the context of smart grid regional linkage. Attached Figure Description

[0019] Figure 1 This is a schematic diagram of a method for automatically generating dispatch operation tickets for regional linkage in a smart grid, provided as an embodiment of the present invention.

[0020] Figure 2 This is a schematic diagram comparing the convergence of node voltages during topology evolution, provided in an embodiment of the present invention.

[0021] Figure 3 This is a schematic diagram illustrating the relationship between the affine envelope and protective constraints of the transient current during cross-regional connectivity, as provided in an embodiment of the present invention.

[0022] Figure 4 This is a schematic diagram of an automatic ticket generation system module for scheduling operation tickets provided in an embodiment of the present invention. Detailed Implementation

[0023] 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 of ordinary skill in the art without creative effort are within the scope of protection of the present invention.

[0024] Example 1, Figure 1This invention presents a method for automatically generating dispatch operation tickets for regional linkage in a smart grid, comprising the following steps: S1. Obtain dispatch instructions and real-time power grid operating conditions, generate initial operation tickets including cross-regional connection operations, and establish a sensitivity matrix of tie line electrical quantities to adjustable equipment control parameters.

[0025] The system obtains the steady-state cross-sectional data and topology of the power grid in real time from the energy management system (EMS) or data acquisition and monitoring control system (SCADA) of the dispatch center through a secure communication interface. The steady-state cross-sectional data includes the active and reactive power output of each generator node, the active and reactive power consumption of each load node, the voltage amplitude and phase angle of each bus node, and the tap position of the transformer and the switching status of the reactive power compensation device. Subsequently, based on the input scheduling instructions, the system automatically generates a preliminary ticket, i.e., the initial operation ticket, containing the standard sequential action sequence of circuit breakers and disconnectors, using a preferred bidirectional breadth-first search algorithm combined with a preset anti-misoperation rule base; the specific steps are as follows: (1) The system constructs a steady-state topology node diagram of the power grid based on the power grid topology, with busbars and switching equipment as nodes and electrical connection lines as edges; secondly, it performs semantic parsing and equipment identification extraction on the input scheduling instructions, matches the unique code of the equipment ledger in the Common Information Model (CIM), and maps the unique code to the corresponding physical node in the steady-state topology node diagram of the power grid, and marks the physical node as the target connected state node; (2) The bidirectional breadth-first search algorithm is set with a maximum search depth threshold (preferably 20 layers in this embodiment) and a node anti-backtracking identifier. It takes the power grid steady-state topology node diagram and the target operating equipment parsed based on the scheduling instructions as input, and the electrical connection relationship of the equipment as the edge structure. It simultaneously expands and traverses the adjacent switch nodes layer by layer from both ends of the current operating state node and the target connected state node through the queue mechanism. During the extended traversal process, the system calls the anti-misoperation rule library (based on the State Grid dispatching operation procedures and historical operation expert experience) pre-installed in the local rule matching engine in real time to verify the legality of each candidate switching action branch. Specifically, the system parses the real-time topology of the power grid into a directed connectivity matrix in graph theory in memory, and compiles the standard five-prevention interlocking logic, equipment electrical interlocking conditions, and secondary protection switching anti-misoperation rules in the anti-misoperation rule library into a computable Boolean logic expression tree. For each candidate switching action branch, the system first performs a trial edge permutation in the directed connectivity matrix and extracts the topology state connectivity features after the permutation. Characteristic variables (e.g., Boolean path connectivity status indication values ​​between nodes on both sides of the switch and the grounding grid or live bus) are then used as input parameters in the Boolean logic expression tree for bottom-up logical evaluation. If the root node output is true, the action branch is deemed legal and included in the initial operation ticket sequence; otherwise, it is discarded. Under the constraint of not exceeding the maximum search depth threshold, the system outputs the shortest safe operation path sequence from the current operating state to the target connectivity state at the intersection of the search space. If the number of search layers exceeds the maximum search depth threshold and the search space still does not intersect, the target connectivity state is deemed unreachable, the search is stopped, and a topology island alarm is output to prompt manual intervention for inspection. (3) Logically connect the switching action nodes in the shortest safe operation path sequence according to the order of execution time, and use the power grid standard terminology semantic mapping table based on the public information model to convert the discrete state variables of the underlying equipment nodes into the corresponding standard scheduling action phrases to obtain the initial operation ticket.

[0026] In this embodiment, the establishment of the sensitivity matrix of the tie line electrical quantities to the control parameters of the adjustable equipment in step S1 includes: S101. Based on the preset balance mapping relationship between node injection power and node state variables, solve for the current node state variables and the node state response feature matrix, as follows: To achieve quantitative compensation, the system extracts branch electrical parameters from the steady-state topology node diagram of the power grid. These parameters include the series resistance, series reactance, ground shunt susceptance of transmission lines, and the non-standard turns ratio of transformers. Subsequently, based on the node voltage method and Kirchhoff's current law, the admittance parameters of each physical branch are combined and superimposed to construct a network-wide node admittance matrix characterizing the electrical connections and admittance characteristics between nodes. Based on this node admittance matrix, an AC power flow balance equation in polar coordinates is constructed to characterize the balance mapping relationship between node injected power and node state variables. Specifically, the node injected power is the net algebraic sum of the generator injected power and load consumed power at each bus node. The node state variables include at least the voltage phase angle and voltage amplitude of each power grid bus node. The calculation formula for the AC power flow balance equation in polar coordinates is as follows: (1) (2) in, Represents a node The active power imbalance, Represents a node The reactive power imbalance, Represents a node The injected active power setpoint, Represents a node The injected reactive power setpoint, and Representing nodes respectively and adjacent nodes voltage amplitude, and These represent the conductance and susceptance of the corresponding elements in the nodal admittance matrix, respectively. Represents a node With nodes The voltage phase angle difference between them; The AC power flow balance equations are solved iteratively using the Newton-Raphson method until the maximum value of the absolute values ​​of the active power imbalance and reactive power imbalance at all nodes satisfies a preset convergence condition. The convergence condition can be set to the maximum value being less than or equal to a preset convergence tolerance threshold (e.g., 10). -4 (per unit value) In the iterative solution process of the Newton-Raphson method, if there are still nodes that do not meet the convergence condition when the number of iterations reaches the preset maximum number of iterations threshold (e.g., 50 times), the system determines that the power flow under the current cross-regional interconnection topology is diverging, and automatically triggers the safety circuit breaker mechanism to immediately terminate the current automatic ticketing process and send a power flow divergence alarm to the dispatching terminal. Conversely, if the Newton-Raphson method has iterated to the point of satisfying the convergence condition before reaching the maximum number of iterations threshold, the system obtains the final stable voltage amplitude and phase angle values ​​of all bus nodes, which constitute the current steady-state voltage distribution solution. In the convergent state, for nodes in the steady-state topology node diagram where the voltage amplitude or voltage phase angle is the variable to be determined, the system calculates the first-order partial derivative analytical expressions of the active power balance equation and reactive power balance equation in the AC power flow balance equation with respect to the voltage phase angle and voltage amplitude variables of the node to be determined, respectively. Subsequently, the system substitutes the specific values ​​of the voltage amplitude and phase angle of each node in the steady-state voltage distribution solution into the first-order partial derivative analytical expression for numerical calculation, thereby obtaining the Jacobian matrix, which reflects the linear mapping relationship between the node power change and the node voltage state variable change under small disturbances, i.e., the characteristic matrix.

[0027] S102. Establish the first partial derivative matrix of the tie-line electrical quantities with respect to the current node state variables, and the second partial derivative matrix of the balance mapping relationship with respect to the adjustable equipment control parameters, as follows: The tie-line electrical quantities include the voltage amplitude and phase angle difference at the boundary nodes of the inter-regional connecting lines; the adjustable equipment control parameters include the generator terminal voltage reference value, transformer tap ratio, and reactive power compensation switching capacity of the parallel capacitor bank; the system constructs a dimension-based system by taking the partial derivatives of the tie-line power flow equations with respect to the voltage amplitude and phase angle at each node. The first partial derivative matrix, where For the characteristic dimension of the electrical quantity of the tie line, The total number of nodes in the network; the tie-line power flow equation is used to characterize cross-regional connected branches (such as boundary nodes). To node The dynamics of active and reactive power transmission over the tie line (between points) are directly controlled by the voltage magnitude and phase angle difference at the boundary nodes. The calculation formula for the tie line power flow equation is as follows: (3) (4) in, This indicates that the cross-regional connection line starts from the boundary node. Flow to the other node Active transmission power, This indicates the corresponding reactive power transmission power. and Representing boundary nodes respectively and peer node voltage amplitude, Represents a node With nodes The voltage phase angle difference between them and These represent the series conductance and series susceptance in the equivalent circuit of the tie line branch, respectively. This indicates the parallel charging susceptance to ground of the connecting line branch; Simultaneously, the system constructs a dimension-based system by taking partial derivatives of the active and reactive power balance equations of all nodes (i.e., the AC power flow balance equations in polar coordinates constructed in step S101) with respect to the control parameters of the adjustable equipment. The second partial derivative matrix, where To control the total number of parameters.

[0028] S103. Perform a concatenation operation on the characteristic matrix, the first partial derivative matrix, and the second partial derivative matrix to obtain the sensitivity matrix, as follows: Based on the chain rule of differentiation and the implicit function theorem, after inverting the Jacobian matrix, the system multiplies it by the first and second partial derivative matrices respectively to form a global linear relationship matrix that can directly map the influence of small changes in equipment control parameters on the electrical quantities of the tie line, i.e., the sensitivity matrix. The cascade derivation formula of the sensitivity matrix is ​​as follows: (5) in, Represents the sensitivity matrix. Represents the electrical quantity vector of the tie line. Represents the current node's state variable vector. This represents the control parameter vector for adjustable equipment. This represents the preset node-injected power balance mapping vector, i.e., the AC power flow balance equation set. Denotes the first partial derivative matrix. The Jacobian matrix represents the characteristic matrix of a node's state response. This represents the second partial derivative matrix.

[0029] This step transforms the nonlinear power grid state into a linear sensitivity mapping, thereby generating the initial operating ticket and providing a clear computational basis for subsequent quantitative compensation and control.

[0030] S2. The switching action of the cross-regional connection operation is equivalent to an impedance change trajectory, and the extreme values ​​of steady-state electrical quantities evolving with the trajectory are extracted. A control parameter compensation value is generated by combining a preset safety threshold with the sensitivity matrix, including: S201. Introduce a continuous homotopy parameter, and configure the admittance of the branch corresponding to the cross-regional connection operation as a correlation term that varies with the homotopy parameter, so that the branch admittance transitions continuously between the open and closed states, forming the impedance change trajectory, as follows: To capture the hidden over-limit risk at the moment of loop closure of the inter-regional tie line circuit breaker and ensure the absolute convergence of steady-state power flow calculations, the system introduces the homotopy continuity method, commonly used in numerical analysis to solve nonlinear ill-conditioned equations, as its technical foundation. By introducing a continuous homotopy parameter, the admittance of the branch corresponding to the inter-regional connection operation is configured as a correlation term that varies with the homotopy parameter, allowing the branch admittance to transition continuously between the open and closed states, forming the impedance change trajectory. This equivalent treatment mathematically relaxes the discrete step closure process of the circuit breaker into a controlled continuous variable evolution process. The formula for the correlation term is as follows: (6) in, Indicates the homotopy parameter of the branch corresponding to the cross-region connectivity operation. The equivalent complex admittance below, This represents the continuous homotopy parameter, whose value range is the real number interval [0, 1]. This represents the minimum constant admittance of the circuit breaker in the open state (e.g., 10). -6 Per-unit value (to simulate the weak leakage conductance in the off state). This represents the actual physical complex admittance of the inter-regional tie line in a fully closed state.

[0031] S202. Substitute the correlation term into the balance mapping relationship, and by incrementing the continuous homotopy parameter, obtain a continuous power flow solution sequence of the current node state variable evolution trajectory with the impedance change; from the solution sequence, extract the voltage amplitude and current amplitude with limit deviations relative to the rated reference value as the extreme values ​​of the steady-state electrical quantity, as follows: The homotopy parameter Start from 0, with a preset step size. (Step size can be set to 0.05) Incrementing sequentially to 1; at the 1st... Homotopion parameters of step size Below, the system will have the corresponding equivalent complex admittance. The algorithm is updated in real time to the network node admittance matrix constructed in S101, and the steady-state voltage distribution solution obtained in the previous step is used as the initial value for the current step. This solution is then substituted into the AC power flow balance equation constructed in S101 for solving. The homotopy parameter... By successively increasing and iteratively solving, a continuous power flow solution sequence is obtained, which includes the voltage magnitude and phase angle of all network nodes under the transition physical state corresponding to each increasing step size during the evolution process. To intuitively verify the computational stability of the above evolution process under complex working conditions Figure 2 The following are comparative figures of measured homotopy evolution of node voltages considering the influence of measurement noise: Figure 2As shown, the method of this invention (blue solid line) introduces a continuous homotopy parameter to mathematically relax the discrete step closure process of the circuit breaker into a controlled continuous variable evolution process. Under the actual simulated operating conditions that take into account measurement noise, the trajectory of this invention exhibits a nonlinear smooth evolution and finally converges stably to the steady-state solution of the closed state when the homotopy parameter is equal to 1. In contrast, the traditional discrete power flow method shown by the red dashed line in the figure fails to converge when the homotopy parameter is close to 0.91 because it cannot handle the ill-conditioned problem of the nonlinear equation caused by topological mutation, and thus cannot complete the final operation ticket calculation. This intuitively demonstrates the robustness of the method of this invention in solving the power flow divergence problem under complex cross-regional connectivity conditions, and ensures the continuity and reliability of the operation ticket calculation process. Subsequently, the system obtains the rated reference value based on the equipment rated parameters pre-stored in the Common Information Model (CIM) equipment ledger. The rated reference value includes the rated voltage reference value (e.g., 110kV, 220kV) of each bus node and the rated current carrying capacity reference value of each line. The system traverses the continuous power flow solution sequence and calculates the maximum difference between the voltage amplitude of each node and the current amplitude of each branch during the evolution process and their rated reference values. The maximum difference is the limit deviation, and the maximum current amplitude corresponding to the limit deviation is locked with the highest or lowest voltage amplitude as the extreme value of the steady-state electrical quantity.

[0032] S203. Based on the deviation between the extreme values ​​of the steady-state electrical quantities and the preset safety thresholds, an electrical quantity over-limit vector is constructed; using the sensitivity matrix, an inverse mapping relationship between the tie-line electrical quantities and the control parameters is constructed, and the over-limit vector is mapped to the adjustment increments of each control parameter to obtain the control parameter compensation values, as follows: The system first compares the extracted steady-state electrical quantity extreme values ​​with preset safety thresholds one by one. Specifically, it performs a unidirectional over-limit check on the maximum current amplitude corresponding to the extreme deviation and the thermal stability current limit of the line in the preset safety threshold (e.g., 1.2 times the rated current carrying capacity). It also compares the highest or lowest voltage amplitude corresponding to the extreme deviation with the upper and lower safety voltage limits of the bus in the preset safety threshold (e.g., 0.95 to 1.05 per unit of the rated voltage). If all steady-state electrical quantity extreme values ​​do not exceed the safe operating range defined by the preset safety threshold, it is determined that there is no steady-state over-limit risk in the current cross-regional connection operation. The system will generate an empty set or a control parameter compensation value with a value of zero and directly trigger the execution of the subsequent transient current envelope prediction step. Conversely, if the steady-state electrical quantity extreme values ​​exceed the safe operating range defined by the preset safety threshold, the system calculates the difference between the current amplitude, voltage amplitude and the corresponding threshold, and arranges all the excess difference values ​​according to the topological order of network nodes and branches to obtain a multi-dimensional electrical quantity over-limit vector. Since the total dimension of the control parameters of all adjustable devices in the network (i.e., the sum of the number of specific equipment nodes of all generators, transformers, and capacitors involved in regulation) is usually greater than the dimension of the electrical quantities that actually exceed the limits, the sensitivity matrix mathematically constitutes an underdetermined system with more unknowns than constraint equations. Therefore, the system uses the weighted minimum norm criterion combined with the Moore-Penrose generalized inverse matrix to construct an inverse mapping relationship. Thus, in the control space containing infinitely many sets of solutions, the minimum norm solution with the minimum control cost is selected as the optimal regulation increment, i.e., the control parameter compensation value. The calculation formula for the control parameter compensation value is as follows: (7) in, This represents the vector of control parameter compensation values, which consists of the adjustment increments of each control parameter obtained from the solution. This represents the sensitivity matrix obtained in step S1. This represents the transpose of the sensitivity matrix. This represents the electrical quantity over-limit vector; This represents the control cost diagonal weight matrix, used to measure the physical cost priority of different types of equipment participating in regulation. The larger the weight value, the higher the cost of mobilizing that equipment. It should be noted that the weight values ​​of the control cost diagonal weight matrix are not only qualitatively set based on professional experience in power grid operation, but also quantitatively allocated by comprehensively considering the physical response attributes of the equipment and the operation and maintenance costs; for the weight values ​​on the diagonal of the weight matrix... The weight value corresponding to each adjustable device Its normalized calculation formula is as follows: (8) in, For the first The mechanical response time of an adjustable device, as specified by the factory or measured on-site. The cost of a single adjustment is calculated based on a comprehensive evaluation of historical operation and maintenance statistics and expert experience. and These are the maximum nominal response time and the maximum converted cost extracted by the system after traversing the entire network's list of currently available regulating equipment. and The preset preference adjustment coefficient, It can be set to 0.7. It can be set to 0.3; The minimum normalization constant is set to a preset value (e.g., 10). -4 This is used to prevent the calculated weights from being zero when the device response time and cost are small, thereby ensuring the absolute numerical stability of the diagonal weight matrix when performing the inversion operation; To illustrate with a specific engineering application scenario: If the system detects that the steady-state extreme value of the bus voltage at a certain boundary node reaches 1.10 per unit in the virtual loop evolution trajectory, exceeding the safety upper limit threshold of 1.05 per unit, the excess difference of 0.05 is extracted as a component input into the electrical quantity excess vector formula (7); under the guidance of the control cost weight matrix, the system automatically calculates the physical adjustment action with the minimum cost, such as lowering the tap position of a main transformer in an adjacent area by 2 levels (assuming that a single level corresponds to a voltage control capability of 0.025 per unit). This specific adjustment action is the generated control parameter compensation value.

[0033] This step combines continuous impedance trajectory evolution with sensitivity inverse mapping to achieve predictive compensation for extreme values ​​exceeding limits during steady-state transition, effectively avoiding power flow calculation divergence caused by topological changes during cross-regional loop closure operations. At the same time, it transforms the passive over-limit termination error reporting in the traditional scheduling system into proactive pre-quantitative control commands.

[0034] S3. Based on the error range of the equivalent parameters of the grid at the other end of the tie line, calculate the transient current envelope at the moment of cross-regional connection through error propagation, and solve the tie line closing phase angle that satisfies the preset protection setting constraints. In this embodiment, the calculation of the transient current envelope at the instant of cross-regional connection in step S3 includes: S301. The error range of the equivalent parameters of the remote power grid is transformed into an affine form that includes the center value and the noise term, as follows: Due to the uncertainty of cross-regional data, in actual dispatching operations, real-time changes in the operating mode of the remote power grid, inherent accuracy errors of boundary measurement elements, and cross-regional communication delays all cause random drift in the equivalent impedance or equivalent potential of the remote end obtained by the local dispatching system, thus forming a non-negligible error range in the physical parameters. Therefore, the system equates the cross-regional tie line and the AC power grid system connected to both sides to a second-order series equivalent transient physical loop model of RLC excited by transient voltage (which can also be extended to a π-type or T-type equivalent state space for specific long-line topologies; this embodiment takes a representative high-frequency oscillation second-order series reference model as an example). The error range of the equivalent parameters of the remote power grid, including the equivalent inductance, equivalent resistance, and equivalent capacitance in the transient physical loop, is transformed into an affine form containing a center value and a noise term. Taking the equivalent inductance of the remote end with an error range as an example, the center value of its error range is extracted, and a non-probabilistic algebraic symbol variable is introduced as an independent noise symbol element. The equivalent inductance is then transformed into an affine variable consisting of the center value and a noise term, as shown in the following formula: (9) (10) (11) in, For the affine form of the equivalent inductance, The center value of the affine form of the equivalent inductance. The noise figure is in affine form of the equivalent inductance. , These are the upper and lower limits of the equivalent inductance error range, respectively. Similarly, the second non-probabilistic algebraic symbolic variable is treated as an independent noise symbol. Based on the error range of the equivalent resistance, the equivalent resistance is transformed into an affine form. ,in It is the affine form of the equivalent resistance. The center value of the affine form of the equivalent resistance. The noise figure is in affine form of the equivalent resistance; further, a third non-probabilistic algebraic symbol variable is used as an independent noise symbol. Based on the error range of the parallel admittance from the terminal network to ground, the equivalent capacitance is transformed into an affine form. ,in This is the affine form of the equivalent capacitance. The center value of the affine form of the equivalent capacitance. The noise figure is in affine form of the equivalent capacitance. It should be noted that the independent noise symbol element , , Throughout the entire algorithm derivation process, no random sampling or specific numerical assignment is performed. Instead, it always serves as an algebraic identifier that tracks the propagation trajectory of error sources and participates in equation analysis. Furthermore, its mathematical boundary is constrained within the closed interval [-1, 1].

[0035] S302. Establish the electromagnetic transient constraint relationship between the transient current of the tie line and the equivalent parameters of the affine form. Specifically, the electromagnetic transient constraint relationship is a set of electromagnetic transient state-space equations constructed based on the RLC second-order series equivalent transient physical loop model, as follows: (12) (13) in, The voltage amplitude of the equivalent power source on both sides of the tie line is obtained by extracting the steady-state voltage amplitude and voltage phase angle of the boundary nodes on both sides of the tie line from the steady-state voltage distribution solution obtained in step S101, and then performing phasor subtraction. The system angular frequency; For transient integral time variables; The candidate closing phase angle represents the initial phase of the AC voltage waveform at the instant the circuit breaker contacts close. It is the affine voltage across the series equivalent capacitor; The transient total current of the tie line flowing through this second-order series equivalent loop, evolving with transient time, is given by the affine form parameters included in the electromagnetic transient constraint formula. , , The transient current of the connecting line also exhibits an affine form.

[0036] S303. For each candidate closing phase angle, the candidate closing phase angle is used as an initial phase condition and substituted into the electromagnetic transient constraint relationship. A step-by-step affine deduction is performed to obtain the transient current affine solution, as follows: According to the preset electrical angle step size (e.g. ),from to Step-by-step scanning of candidate closing phase angles; for each candidate closing phase angle scanned, it is directly substituted into the voltage source initial phase variable in the electromagnetic transient state space equations. Within this system, affine deduction is performed step-by-step. Before performing the affine deduction, the system assigns initial values ​​to the state variables of the electromagnetic transient state space equations based on the actual physical operation procedures of the power grid. Specifically, since the inter-regional tie line is in a physically disconnected open-circuit state before the closing operation, and the residual charge on the line has been completely released through the standard dispatching operation before closing (such as grounding switch discharge), the system will set the instant the circuit breaker contacts close (i.e., the transient integral time variable) as the time variable changes. The initial tie-line transient total current at time (i.e.) is set to zero (i.e.) ), and set the transient voltage across the initial series equivalent capacitor to zero (i.e. Subsequently, the time domain range of the affine deduction is set to one power frequency cycle from the moment the circuit breaker is connected (e.g., 0 to 0.02 seconds in a 50Hz system), and the time domain of the affine deduction is discretized and numerically integrated using a preset time step (e.g., 100 microseconds); at each time step divided by the preset time step, the electromagnetic transient state space equations are solved using an implicit trapezoidal integration algorithm to obtain the transient current affine solution for that time step; It should be noted that the implicit trapezoidal integral algorithm is a classic deterministic mathematical tool for solving ordinary differential equations in the field of numerical analysis. Its core principle is to discretize continuous differential terms into difference schemes based on consecutive time steps, thereby transforming complex differential equations into algebraic recursive equations that can be directly solved at each time step. Furthermore, during the integration process, to prevent the dimensional expansion and envelope boundary distortion of independent noise symbols due to high-order truncation errors in affine arithmetic during nonlinear simplification and division operations, the system introduces Chebyshev optimal approximation of nonlinear terms and a threshold-based affine noise symbol aggregation mechanism. Specifically, when handling nonlinear operations such as division, Chebyshev approximation is used to find the linear tolerance band with the smallest error. After the algebraic recursive calculation is completed at each integration time step, the system performs truncation error judgment on the newly generated transient current affine solution, removing small high-order noise terms (i.e., noise terms whose absolute value of the weight coefficient is less than a preset truncation threshold, for example, setting the truncation threshold to 10). -5 The absolute values ​​of the per-unit values ​​are combined to obtain a residual symbolic element whose mathematical boundary constraints are within the closed interval [-1, 1]. This ensures that the mathematical envelope absolutely covers the real evolution trajectory, while constraining the number of noise terms in the affine expression to a preset dimension (e.g., three independent physical error sources including equivalent resistance, inductance and capacitance, and one truncated residual source, fixed to a total of four dimensions), thus guaranteeing the convergence and high fidelity of long-term transient deduction. In solving the algebraic recurrence equation, since the input equivalent parameters all contain independent noise symbols with tracking errors, the system calls the basic addition, subtraction, multiplication, and division rules of affine arithmetic (that is, performing regular algebraic operations on the central terms of each constant, and merging and simplifying coefficients with the same noise symbols), thus directly deriving the transient current solution, which also presents an affine form, at the algebraic level. Finally, at any time step, the obtained transient current affine solution is expressed as a linear superposition of the central term and a series of noise symbols with weighted coefficients. For example, the affine solution at a certain time step is... ,in The transient current is the center value at that moment. , , , These are the weighting coefficients for the corresponding noise term and residual term, respectively. The absolute value of the weighting coefficients represents the specific influence of the inductance, resistance, and capacitance errors at the other end, as well as the higher-order truncation residuals, on the fluctuation of the current value at the current moment.

[0037] S304. Perform algebraic operations on the center value and weights of each noise term of the affine solution to obtain the upper and lower current limits corresponding to each time step. Then, connect the upper and lower current limits in time sequence to generate the transient current envelope corresponding to each candidate closing phase angle, as follows: For each time step, algebraic operations are performed on the center value of the transient current affine solution and the weights of each noise term to obtain the absolute current boundaries corresponding to each time step, i.e., the upper and lower limits of the current. Specifically, the absolute values ​​of the weight coefficients of each noise term are taken and summed. Then, the summation result is added to and subtracted from the center value, respectively, to obtain the upper and lower limits of the true envelope distribution. For example, the affine solution for a certain time step is... Then the upper and lower limits of the transient current at this time step are respectively and ; After completing the derivation of the entire transient integral time domain, the upper limit values ​​calculated at each time step are connected point by point to form an upper boundary curve according to the temporal sequence of each time step divided by the preset time step, and the lower limit values ​​are connected point by point to form a lower boundary curve, thereby forming a closed envelope shape, namely the transient current envelope. The transient current envelope represents all the limit boundaries that the transient impact current at the moment of cross-regional connection can reach over time under the uncertain operating condition of arbitrary combination fluctuation of the parameters of the opposite end of the power grid within the error range.

[0038] In this embodiment, the step S3 of solving the tie-line closing phase angle that satisfies the preset protection setting constraints includes: S305. Extract the peak value of the transient current envelope corresponding to each candidate closing phase angle, and select the set of continuous candidate closing phase angles whose peak values ​​satisfy the preset protection setting constraints as the phase safety interval. Then, select the tie-line closing phase angle based on the preset safety assessment strategy, as follows: It should be noted that the preset protection setting value is automatically obtained by the dispatching system from the relay protection setting sheet data interface, and is characterized as the maximum safe current threshold allowed to flow through the power grid equipment (e.g., 1.5kA). The protection setting value is used to trigger the circuit breaker to trip when the loop transient impact current exceeds the limit, so as to prevent the cross-regional tie line and its associated core equipment (such as transformers, current transformers, etc.) from dynamic stability failure or thermal stability damage. The system extracts the upper and lower absolute peak values ​​of the transient current envelope corresponding to each candidate closing phase angle. Candidate closing phase angles whose upper and lower absolute peak values ​​are both less than the protection setting are determined to be safe phase angles. Numerically adjacent safe phase angles are directly merged and connected according to one-dimensional algebraic interval segments to form continuous phase safety intervals, for example, forming... as well as Two safe zones; like Figure 3 As shown, Figure 3A diagram showing the relationship between the transient current evolution envelope and protection constraints derived from a typical closing phase angle is presented. The gray shaded area in the diagram represents the transient current envelope obtained through affine derivation under uncertain operating conditions where there is an error range in the parameters of the opposite power grid. This envelope completely covers the nominal trajectory of the transient impact current, which includes higher harmonics and DC offset. By comparing the upper and lower absolute peak values ​​of this envelope with the preset protection setting and its opposite (i.e., the upper and lower limits of the protection setting) in real time, if the envelope does not break through the protection setting boundary throughout the entire transient integral time domain, the typical closing phase angle is determined to be a safe phase angle that satisfies the protection setting constraints. It should be noted that if, after traversing all candidate closing phase angles, no safe phase angle with an absolute peak value of the upper or lower limit less than the protection setting is found, it is determined that under the current grid topology and parameter error extreme value conditions, the loop closing operation has a high risk of relay protection maloperation and tripping. The system will automatically interrupt the subsequent operation ticketing process and trigger a "no safe closing window" dispatch alarm, prompting dispatchers to perform manual intervention or adjust the grid operation mode. When selecting the tie-line closing phase angle, the system can perform final optimization from the phase safety range based on a preset safety assessment strategy; specifically: 1) If the system is configured in safety margin optimization mode, considering the inherent millisecond-level action time error of the mechanical mechanism of the field high-voltage circuit breaker during the period from receiving the command to the actual contact closing, in order to prevent this time error from causing the actual physical closing phase angle to drift out of the safety range, the system extracts the phase safety range with the largest span (i.e., the difference between the upper and lower limits of the phase safety range), and selects the midpoint phase angle of this safety range as the tie-line closing phase angle, thereby providing the maximum safety tolerance margin for mechanical action delay; 2) If the system is configured in electromagnetic impulse suppression mode to minimize the limiting electromagnetic force applied to the equipment insulation at the moment of loop closure, the system will traverse all safe phase angles within the safe phase interval, compare the absolute peak values ​​of the upper and lower limits of the transient current envelope corresponding to each phase angle, and select the phase angle with the smallest maximum value among the upper and lower limit absolute peak values ​​as the tie-line closing phase angle; 3) If the system is configured in thermal stability optimization mode to reduce the total heat generated on the line during the transient transition process, the system will perform time integration on the square value of the transient current envelope of each safe phase angle (to characterize the actual cumulative Joule heating effect), and select the phase angle with the smallest integral value as the tie-line closing phase angle; This step, by combining transient envelope derivation using affine arithmetic with protection setting constraints, quantifies the current boundary of electromagnetic transient impact under uncertain operating conditions where cross-regional parameters have errors. Furthermore, by optimizing the closing phase angle of the tie line through a safety assessment strategy, it effectively reduces the risk of relay protection maloperation caused by transient impact current exceeding the limit at the moment of loop closing, and improves the safety and success rate of cross-regional linkage operation.

[0039] S4. Integrate the control parameter compensation value and the closing phase angle into the initial operation ticket to generate the final operation ticket, including: S401. The control parameter compensation value is converted into the corresponding equipment adjustment command, and inserted as a preliminary step before the closing command for the cross-zone connection operation in the initial operation ticket, as follows: As described in step S203, the calculated control parameter compensation values ​​have been visualized as discrete physical adjustment actions in physical semantics. At this time, the system retrieves the pre-configured substation equipment ledger and control mapping dictionary. The substation equipment ledger records the scheduling dual naming identifiers and physical attribute boundaries of specific equipment in the real power grid, and the control mapping dictionary establishes the addressing binding relationship between the control variable nodes of each dimension in the underlying algorithm model and the remote communication point table address of the field equipment. Based on the control mapping dictionary, the control parameter identifiers at the pure algorithm level (i.e., the topological numbers of mathematical variables that uniquely identify the objects being regulated in the physical regulation actions in the power flow equations and sensitivity matrices) are used as index keywords for relation matching to obtain the remote communication point table addresses that can be recognized by the field machines. Simultaneously, the substation equipment ledger is retrieved using the control parameter identifiers or remote communication point table addresses as association keys to obtain the unique scheduling dual-naming identifier and current actual operating status of the physical equipment corresponding to the regulated object. Furthermore, the physical regulation actions are converted into equipment regulation commands conforming to the International Electrotechnical Commission (IEC) standard scheduling communication specifications (e.g., IEC 61850 protocol). For example, for the control parameter compensation value "reduce the tap position of a main transformer in an adjacent area by 2 levels," the system retrieves the corresponding "Main Transformer No. 2 of Substation A" from the control mapping dictionary, and the ledger shows that it is currently at level 5. The system then converts the control parameter compensation value into a standardized equipment regulation command text, "adjust the on-load tap changer of Main Transformer No. 2 of Substation A from the current level 5 to level 3," and simultaneously generates the corresponding hexadecimal remote control message. Subsequently, when constructing the timing logic linked list of the operation ticket, the system will arrange the generated equipment adjustment instructions such as transformer tap-off or capacitor switching in series on the time axis before the final closing instruction of the cross-regional tie line circuit breaker, thereby ensuring that the steady-state voltage and power flow distribution of the local power grid have been adjusted to the optimal state to eliminate the initial deviation before the physical closing action of the tie line is implemented.

[0040] S402. The closing phase angle of the tie line is used as a trigger setting parameter and configured in the execution attribute of the closing command, as follows: The calculated phase angle value for the tie line closing is written as a configuration parameter into the execution parameter node under the closing command data structure of the cross-regional tie line circuit breaker. For example, in the underlying communication message sent to the substation site intelligent phase selection closing device (POW controller), the system appends "PhaseAngle=" to the conventional circuit breaker control command identifier. The extended field; the extended field causes the field control terminal to not act immediately after receiving the closing permission, but to enter waveform monitoring state, and to wait for the AC voltage waveform to cross zero and reach the specified phase angle within a preset time tolerance window (e.g., ...). Within milliseconds, the closing action of the circuit breaker's mechanical operating mechanism is triggered.

[0041] S403. Perform logical verification and format encapsulation on the initial operation ticket that has completed instruction integration and attribute configuration to obtain the final operation ticket, as follows: In the logic verification stage, the system performs timing and physical limit checks according to power safety regulations. Specific verification rules include: first, verifying the timing logic by traversing the operation ticket chain to check whether the timestamps and execution sequences of all preceding voltage or power regulation commands are before the closing command, thus avoiding the risk of limit violations caused by the reversed execution sequence of the loop closing operation preceding the steady-state compensation operation; second, verifying the parameter logic by checking whether the closing phase angle of the connected tie line falls within the specified range. Within the effective electrical cycle range and without deviating from the calculated phase safety range, at the same time check whether the final tap of the transformer tap adjustment command exceeds the limit tap range allowed by its physical nameplate (such as taps 1 to 17). After all logical checks pass, the system performs a format encapsulation step: the operation sequence, after being arranged in a time sequence and with parameters attached, is encapsulated in a message structure according to substation communication network and system standards such as the International Electrotechnical Commission IEC61850. A cryptographic digital signature and message authentication code are then added to the encapsulated message using a secure hash algorithm (such as the SHA-256 algorithm, whose output digest length is 256 bits) to prevent the instructions from being illegally tampered with during the network transmission process. Finally, a final operation ticket is generated, containing the complete operation sequence, control parameters (i.e., the set values ​​of the closing phase angle and equipment adjustment instructions), and an anti-tampering verification digest generated based on the secure hash algorithm.

[0042] This step integrates and encapsulates steady-state control commands and transient closing phase angle parameters in terms of timing and data structure, thereby achieving coordination between the macro-level scheduling process and the underlying electrical waveform control, and ensuring the timing correctness and data integrity of the operation commands at the field automation execution level.

[0043] Example 2, Figure 4 An automatic ticketing system for scheduling operations, used to implement the method described in any of Embodiment 1, is provided, comprising the following modules: The initial ticket generation module is used to acquire dispatch instructions and real-time power grid operating conditions, generate initial operation tickets including cross-regional connection operations, and establish a sensitivity matrix of tie line electrical quantities to adjustable equipment control parameters. The steady-state compensation module is used to equate the switching action of the cross-regional connection operation to an impedance change trajectory, extract the extreme values ​​of steady-state electrical quantities that evolve with the trajectory, and generate control parameter compensation values ​​by combining a preset safety threshold with the sensitivity matrix. The transient phase-finding module is used to calculate the transient current envelope at the moment of cross-regional connection based on the error range of the equivalent parameters of the grid at the other end of the tie line through error propagation, and to solve the tie line closing phase angle that satisfies the preset protection setting constraints. An integrated ticketing module is used to integrate the control parameter compensation value and the closing phase angle into the initial operation ticket to generate the final operation ticket.

[0044] The above formulas are all dimensionless calculations. The formulas are derived from software simulations using a large amount of collected data, and are the closest to the real situation. The preset parameters in the formulas are set by those skilled in the art according to the actual situation.

[0045] The above embodiments can be implemented, in whole or in part, by software, hardware, firmware, or any other combination thereof. When implemented using software, the above embodiments can be implemented, in whole or in part, in the form of a computer program product.

[0046] Those skilled in the art will recognize that the modules and algorithm steps of the various examples described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, or a combination of computer software and electronic hardware. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of this application.

[0047] In addition, the functional modules in the various embodiments of this application can be integrated into one processing module, or each module can exist physically separately, or two or more modules can be integrated into one module.

[0048] The above description is merely a specific embodiment of this application, but the scope of protection of this application is not limited thereto. Any variations or substitutions that can be easily conceived by those skilled in the art within the scope of the technology disclosed in this application should be included within the scope of protection of this application. Therefore, the scope of protection of this application should be determined by the scope of the claims.

[0049] In conclusion, the above description is only a preferred embodiment of the present invention and is not intended to limit the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the protection scope of the present invention.

Claims

1. A method for automatically generating dispatch operation tickets for regional linkage in a smart grid, characterized in that, Includes the following steps: Obtain dispatch instructions and real-time power grid operating conditions, generate initial operation tickets including cross-regional interconnection operations, and establish a sensitivity matrix of tie line electrical quantities to adjustable equipment control parameters; The switching action of the cross-regional connection operation is equivalent to an impedance change trajectory, and the extreme values ​​of steady-state electrical quantities that evolve with the trajectory are extracted. The control parameter compensation values ​​are generated by combining the preset safety threshold with the sensitivity matrix. Based on the error range of the equivalent parameters of the grid at the other end of the tie line, the transient current envelope at the moment of cross-regional connection is calculated through error propagation, and the tie line closing phase angle that satisfies the preset protection setting constraints is solved. The control parameter compensation value and the closing phase angle are integrated into the initial operation ticket to generate the final operation ticket.

2. The method according to claim 1, characterized in that, The establishment of the sensitivity matrix of the tie line electrical quantities to the control parameters of the adjustable equipment includes: Based on the preset balance mapping relationship between node injection power and node state variables, solve for the current node state variables and node state response feature matrix; Establish a first partial derivative matrix of the tie line electrical quantities with respect to the current node state variables, and a second partial derivative matrix of the balance mapping relationship with respect to the adjustable equipment control parameters; The sensitivity matrix is ​​obtained by cascading the feature matrix, the first partial derivative matrix, and the second partial derivative matrix.

3. The method according to claim 2, characterized in that, The equivalent impedance change trajectory includes: By introducing a continuous homotopy parameter, the admittance of the branch corresponding to the cross-regional connection operation is configured as a correlation term that varies with the homotopy parameter, so that the branch admittance transitions continuously between the open and closed states, forming the impedance change trajectory.

4. The method according to claim 3, characterized in that, The extraction of the extreme values ​​of steady-state electrical quantities that evolve with the trajectory includes: Substitute the correlation terms into the balance mapping relationship, and by incrementing the continuous homotopy parameter, obtain the continuous power flow solution sequence of the current node state variable as the impedance changes trajectory. From the solution sequence, the voltage amplitude and current amplitude that have a limit deviation relative to the rated reference value are extracted as the extreme values ​​of the steady-state electrical quantity.

5. The method according to claim 4, characterized in that, The generation of control parameter compensation values ​​includes: Based on the deviation between the extreme values ​​of the steady-state electrical quantities and the preset safety threshold, an electrical quantity over-limit vector is constructed; Using the sensitivity matrix, an inverse mapping relationship between the tie line electrical quantities and the control parameters is constructed, and the over-limit vector is mapped to the adjustment increment of each control parameter to obtain the control parameter compensation value.

6. The method according to claim 5, characterized in that, The calculation of the transient current envelope at the instant of cross-regional connectivity includes: The error range of the equivalent parameters of the opposite power grid is transformed into an affine form that includes the center value and noise term; Establish electromagnetic transient constraint relationships between the transient current of the tie line and the equivalent parameters of the affine form; After iterating through the candidate closing phase angles and performing affine deduction based on the electromagnetic transient constraint relationship to obtain the upper and lower current limits for each time step, the transient current envelope corresponding to each candidate closing phase angle is generated.

7. The method according to claim 6, characterized in that, The generation of the transient current envelope corresponding to each candidate closing phase angle includes: Substitute the candidate closing phase angle as the initial phase condition into the electromagnetic transient constraint relationship, and perform time-step affine deduction to obtain the transient current affine solution. Algebraic operations are performed on the center value and the weights of each noise term of the affine solution to obtain the upper and lower limits of the current corresponding to each time step. The upper and lower current values ​​are connected sequentially to generate the transient current envelope.

8. The method according to claim 7, characterized in that, The process of determining the tie-line closing phase angle that satisfies the preset protection setting constraints includes: Extract the peak value of the transient current envelope corresponding to each candidate closing phase angle, and select the set of continuous candidate closing phase angles whose peak values ​​satisfy the preset protection setting constraints as the phase safety interval; Based on a preset safety assessment strategy, the tie-line closing phase angle is selected from the phase safety interval.

9. The method according to claim 8, characterized in that, The generation of the final operation ticket includes: The control parameter compensation value is converted into the corresponding equipment adjustment command and inserted as a preliminary step before the closing command of the cross-zone connection operation in the initial operation ticket; The closing phase angle of the tie line is used as a trigger setting parameter and configured in the execution attribute of the closing command; The initial operation ticket, which has completed instruction integration and attribute configuration, is logically validated and formatted to obtain the final operation ticket.

10. An automatic ticketing system for implementing the method as described in any one of claims 1 to 9, characterized in that, Includes the following modules: The initial ticket generation module is used to acquire dispatch instructions and real-time power grid operating conditions, generate initial operation tickets including cross-regional connection operations, and establish a sensitivity matrix of tie line electrical quantities to adjustable equipment control parameters. The steady-state compensation module is used to equate the switching action of the cross-regional connection operation to an impedance change trajectory, extract the extreme values ​​of steady-state electrical quantities that evolve with the trajectory, and generate control parameter compensation values ​​by combining a preset safety threshold with the sensitivity matrix. The transient phase-finding module is used to calculate the transient current envelope at the moment of cross-regional connection based on the error range of the equivalent parameters of the grid at the other end of the tie line through error propagation, and to solve the tie line closing phase angle that satisfies the preset protection setting constraints. An integrated ticketing module is used to integrate the control parameter compensation value and the closing phase angle into the initial operation ticket to generate the final operation ticket.

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