Two-step optimization method and device for inter-provincial reserve market clearing

Abstract

The application provides a two-step optimization method and device suitable for inter-provincial reserve market clearing verification. The application improves the calculation efficiency of large-scale power grid safety constraint unit commitment by first-step large-time-granularity unit commitment optimization. Then, the unit commitment is fixed, and the second-step small-time-granularity economic dispatch is used to improve the accuracy of safety constraint economic dispatch. The optimization model introduces double balancing constraints of provincial power supply and demand and port planning, and realizes integrated adjustment of regional power grid direct-regulation units and provincial power grid regulation and management units.

Description

Technical Field

[0001] This invention relates to the technical field of power dispatch automation, and in particular to a two-step optimization method adapted to the clearing and verification of inter-provincial reserve market in regional power grids. Background Technology

[0002] In response to the current situation of increased external power imports and the growing uncertainties in power grid operation brought about by the rapid development of new energy sources in the region, the time scale for resource allocation will be extended from the medium to long term to the day-ahead and intraday. When the predicted reserve capacity of the provincial (municipal) power grid in the region cannot meet the grid security requirements, the backup ancillary service market will be activated to mobilize resources across the region to provide support. This market-based approach will incentivize all power generation entities in the grid to release their regulation potential, achieve inter-provincial mutual assistance, enhance the regional power grid's ability to withstand uncertainties, and contribute to the region's clean and low-carbon development.

[0003] Currently, a clearing mechanism for inter-provincial reserve ancillary services has been proposed. However, existing safety-constrained unit combination and economic dispatch algorithms generally focus on planning under the provincial power grid's three-fairness dispatch model and competitive clearing under the market model, or further on the regional and provincial power grid acceptance capacity analysis. They have not truly achieved combination optimization and planning for the East China regional power grid, nor have they established corresponding optimization models for the inter-provincial transfer mechanism of reserve ancillary services. Summary of the Invention

[0004] This invention addresses the lack of a safety verification optimization method for the clearing results of the inter-provincial reserve market in existing technologies. Combining the domestic market-based inter-provincial allocation and clearing mechanism for reserve auxiliary services, it proposes a two-step optimization method adapted to the verification of the inter-provincial reserve market clearing results in regional power grids. This method solves the problems of low efficiency in solving unit combination in existing technologies and the lack of a targeted optimization model for verifying the inter-provincial reserve clearing results in regional power grids. It provides a practical and effective optimization method for verifying the safety and feasibility of the inter-provincial reserve market clearing results in regional power grids, filling the technological gap in the field of inter-provincial reserve market clearing verification.

[0005] The present invention adopts the following technical solution.

[0006] On the one hand, the present invention provides a two-step optimization method adapted to the clearing verification of the inter-provincial reserve market, including the following steps:

[0007] Step S1: Establish inter-provincial reserve market clearing verification scenario data;

[0008] Step S2: Establish an inter-provincial reserve market clearing verification model;

[0009] Step S3: Based on the scenario data described in S1, set the first time period granularity of the verification model and the decision variables of the first step optimization, and perform the first step safety constraint unit combination optimization solution to obtain the unit results. The unit results include the gas turbine time period granularity start-up and shutdown status.

[0010] Step S4: Reset the granularity of the second time period of the verification model and the decision variables of the second optimization step. The granularity of the second time period is smaller than that of the first time period. The start-up and shutdown status of the fixed time period is determined according to the start-up and shutdown status of the gas turbine time period.

[0011] Based on the scenario data described in S1, the second step of safety-constrained economic scheduling optimization is performed to obtain the cross section, branch, and equipment power flow.

[0012] Step S5: Determine if there are any sections, branches, or equipment exceeding the limits. If there are, the clearing process needs to be restarted. Otherwise, it indicates that the clearing result of the inter-provincial standby market can be executed.

[0013] Optionally, it also includes step S6, which outputs the unit combination, unit output, port changes and power flow information for each time period obtained from the optimization in the first step and the optimization in the second step.

[0014] Furthermore, the scenario data mentioned in step S1 includes system data, unit data, tie-line plan data, load data, unit group data, and sensitivity data.

[0015] Furthermore, the system data includes time period information, system load, and system reserve requirements; the unit data includes basic unit information, unit calculation parameters, unit initial state, unit output limits, and unit ramp rate; the tie line planning data includes basic tie line information and tie line planned power; the load data includes bus load forecast; the unit group data includes unit group power limits and unit group energy limits; and the sensitivity data includes the generation transfer distribution factor of unit and load injected power on line and cross-sectional power flow.

[0016] Furthermore, the objective function of the inter-provincial reserve market clearing verification model for the regional power grid described in step S2 is:

[0017]

[0018] In the formula: Indicates the total number of generating units; Indicates the total number of time periods; The cost of the output deviation of unit i at time t; , They represent provincial power grids respectively. Time period The increments of input and output (i.e., changes in the inlet / outlet), decision variables; This represents the penalty factor used to optimize network flow constraints in line l during market clearing. , These represent the forward and reverse power flow relaxation variables of line l, respectively. Total number of lines; The penalty factor represents the network flow constraint used for market clearing optimization section s; , Let S represent the forward and reverse tidal current relaxation variables of section s, respectively. This indicates the total number of cross-sections.

[0019] This model models the positive and negative deviations of unit output adjustment separately to realize the different allocation requirements of the unit for positive and negative deviations. The output adjustment cost of unit i at time t can be obtained as follows:

[0020]

[0021] in Positive deviation adjustment cost Negative deviation adjustment cost.

[0022] Furthermore, the constraints of the inter-provincial reserve market clearing verification model of the regional power grid include provincial power generation and consumption balance constraints, provincial sub-balance constraints, unit operation constraints, unit group constraints, network security constraints, and practicality constraints.

[0023] The unit operation constraints include upper and lower limits of unit output, maximum number of start-ups and shutdowns, minimum start-up and shutdown time, and unit ramp-up and ramp-down constraints.

[0024] Unit group constraints include unit group output constraints and unit group power constraints;

[0025] The network security constraints include line power flow constraints and cross-sectional power flow constraints.

[0026] The practical constraints include fixed output constraints of the unit and fixed start-stop mode constraints of the unit.

[0027] Furthermore, based on the scenario data described in S1, the first time period granularity (time period granularity of 1 hour, 24 time periods in 1 day) of the verification model described in step S2 and the decision variables optimized in the first step (including gas turbine start-up and shutdown, and thermal power unit output) are set, a mathematical model adapted to the safety constraint unit combination algorithm is generated and solved to obtain the gas turbine start-up and shutdown at the hourly granularity and the thermal power unit output.

[0028] Furthermore, step S4, based on the calculation scenario constructed in step S1, sets the second time period granularity (the second time period granularity is smaller than the first time period granularity, the second time period granularity is 15 minutes, and there are 96 time periods in 1 day) of the optimized model in step S2 and the decision variable (power output of thermal power units) of the second step optimization. Based on the start-up and shutdown result status of the gas turbine hourly granularity in step S3, the start-up and shutdown status of the gas turbine is fixed at a 15-minute granularity. The inter-provincial reserve market clearing verification model is then solved to obtain the 15-minute granularity power output plan, cross-section / branch and equipment power flow of the gas turbine and thermal power.

[0029] Furthermore, step S5, based on the flow rate and limit of the cross-section / branch / equipment calculated in step S4, determines whether there are any cross-section / branch / equipment exceeding the limit. If the limit is exceeded, it indicates that the inter-provincial reserve market clearing result is unreasonable and needs to be cleared again; if the limit is not exceeded, it indicates that the inter-provincial reserve market clearing result is executable and is issued to each provincial power grid for tracking and implementation.

[0030] Furthermore, step S6 outputs the gas turbine start-up and shutdown status calculated in step S3, and the unit output, cross-sectional / equipment / branch power flow and clearing result feasibility information calculated in step S4, and sends them to the inter-provincial backup auxiliary service technical support system.

[0031] On the other hand, the present invention also provides a two-step optimization method device adapted to the clearing verification of the inter-provincial reserve market, including: a data acquisition module, a model building module, a first optimization solution module, a second optimization solution module, and a clearing result determination module;

[0032] The data acquisition module is used to acquire data on the inter-provincial reserve market clearing verification scenario;

[0033] The model building module is used to build an inter-provincial reserve market clearing verification model;

[0034] The first optimization solution module is used to set the first time period granularity and the first step optimization decision variables of the verification model based on the scenario data, and perform the first step safety constraint unit combination optimization solution on the inter-provincial standby market clearing verification model to obtain the gas turbine first time period granularity start-up and shutdown status.

[0035] The second optimization solution module is used to set the second time period granularity and the decision variables of the second optimization step of the verification model. The granularity of the second time period is smaller than that of the first time period. The start-up and shutdown status of the gas turbine is fixed according to the start-up and shutdown status of the first time period. The second step of safety constraint unit combination optimization solution is performed on the inter-provincial reserve market clearing verification model to obtain the cross section, branch and equipment power flow.

[0036] The clearing result determination module is used to determine whether there are any sections, branches, or equipment exceeding the limits. If there are any sections, branches, or equipment exceeding the limits, clearing needs to be done again. Otherwise, it indicates that the clearing result of the inter-provincial standby market can be executed.

[0037] Furthermore, the objective function of the inter-provincial reserve market clearing verification model established by the model building module is expressed as follows:

[0038]

[0039] In the formula: Indicates the total number of generating units; Indicates the total number of time periods; The cost of the output deviation of unit i at time t; Indicates provincial power grid Time period The incremental amount received, Indicates provincial power grid Time period The incremental amount of data sent out and For decision variables; This represents the penalty factor used to optimize network flow constraints in line l during market clearing. , These represent the forward and reverse power flow relaxation variables of line l, respectively. Total number of lines; The penalty factor represents the network flow constraint used for market clearing optimization section s; , Let S represent the forward and reverse tidal current relaxation variables of section s, respectively. Indicates the total number of cross-sections. .

[0040] Compared with existing technologies, this invention proposes a two-step optimization method adapted to the clearing and verification of inter-provincial reserve markets in regional power grids, based on the principles of safety-constrained unit combination and economic dispatch algorithms. The first step, large-time-granularity unit combination optimization, improves the computational efficiency of large-scale power grid safety-constrained unit combination. Then, with the unit combination fixed, the second step, small-time-granularity economic dispatch, improves the accuracy of safety-constrained economic dispatch. The optimization model introduces dual-balance constraints of provincial generation and consumption and regional planning, achieving integrated adjustment of directly dispatched units in the regional power grid and dispatched units in the provincial power grid. This invention relies on a mature theoretical foundation and has universality. Furthermore, the two-step optimization model boasts high computational efficiency and accuracy, filling a technological gap in the field of inter-provincial reserve clearing and verification in domestic regional power grids. Attached Figure Description

[0041] Figure 1This is a schematic diagram illustrating the segmented adjustment cost of positive deviation adjustment of unit output in a specific embodiment of the present invention;

[0042] Figure 2 This is a schematic diagram of the segmented adjustment cost function for adjusting the positive deviation of unit output in a specific embodiment of the present invention;

[0043] Figure 3 This invention provides a two-step optimization method for clearing and verifying the inter-provincial reserve market of regional power grids, which is adapted to specific embodiments of the present invention. Detailed Implementation

[0044] The following is in conjunction with the appendix Figure 3 The embodiments of the present invention will be further described below. The following examples are only used to more clearly illustrate the technical solutions of the present invention, and should not be used to limit the scope of protection of the present invention.

[0045] like Figure 3 As shown, the embodiments of the present invention include the following steps:

[0046] Step S1: Establish a scenario for clearing and verifying the inter-provincial reserve market of the regional power grid;

[0047] Step S2: Establish a clearing verification model for the inter-provincial reserve market of the regional power grid;

[0048] Step S3: Based on the scenario data in S1, set the time period granularity and decision variables of the verification model in step S2, and execute the first step of safety constraint unit combination optimization solution;

[0049] Step S4: Based on the scenario data of S1 and the unit results of step S3, set the time period granularity and decision variables of step S2, and execute the second step of safety-constrained economic dispatch optimization solution.

[0050] Step S5: Determine if there are any violations of limits for cross-sections, branch lines, or equipment;

[0051] Step S6: Output the unit combination, unit output, gate change and power flow information for each time period.

[0052] The basic data in step S1 includes: 1) System data: time period information, provincial load; 2) Unit data: basic unit information, unit calculation parameters, unit energy quotation, unit initial state, unit power constraints, unit ramp rate; 3) Tie line planning data: basic tie line information, tie line planned power; 4) Load data: bus load forecast; 5) Unit group: unit group power limit, unit group power limit; 6) Sensitivity data: generation transfer distribution factor of unit and load injected power on line and cross-sectional power flow.

[0053] Sensitivity data is obtained by acquiring the latest power grid physical model and real-time operation data, and is calculated using the PQ decoupling method.

[0054] The objective function of the inter-provincial reserve market clearing verification model for the regional power grid described in step S2 is:

[0055] (1)

[0056] In the formula: Indicates the total number of generating units; Indicates the total number of time periods; The cost of the output deviation of unit i at time t; , They represent provincial power grids respectively. Time period The increments of input and output (i.e., changes in the inlet / outlet), decision variables; This represents the penalty factor used to optimize network flow constraints in line l during market clearing. , These represent the forward and reverse power flow relaxation variables of line l, respectively. Total number of lines; The penalty factor represents the network flow constraint used for market clearing optimization section s; , Let S represent the forward and reverse tidal current relaxation variables of section s, respectively. This indicates the total number of cross-sections.

[0057] The deviation cost in the optimization objective is caused by the deviation between the optimized output and the initial output, which will be further explained below. This model models the positive and negative deviations of the unit output adjustment separately to realize the different allocation requirements of the unit for positive and negative deviations.

[0058] Unit output adjustment constraint modeling:

[0059] (2)

[0060] In the formula: For the unit exist Output adjusted in real time; For the unit exist Initial output at any given moment; For the unit exist Positive adjustment amount at any given time; For the unit exist The negative adjustment amount at any given time.

[0061] To facilitate the control and allocation strategy of deviation, a segmented adjustment cost for the unit deviation adjustment amount can be introduced, as shown in the figure. As the amount of change increases, the adjustment cost will also increase.

[0062] After adopting a segmented incremental adjustment cost, the adjustment cost increases rapidly as the unit output changes, such as... Figure 1 As shown, by controlling the adjustment costs of each unit in each deviation range, different deviation allocation effects can be achieved.

[0063] right The process is segmented, and a small incremental adjustment cost is set for each segment. The positive deviation adjustment cost is thus obtained as:

[0064] (3)

[0065] In the formula: S is the total number of segments in the piecewise function; δ + i,t,s Let λ be the change of unit i in the s-th segment of the piecewise function at time t, and be a non-negative value; + i,s Let be the adjustment cost of unit i in the s-th segment of its piecewise function.

[0066] The change in unit output is expressed by segmented cumulative summation:

[0067] (4)

[0068] (5)

[0069] In the formula: P + i,s This represents the endpoint power of each segment interval in the piecewise function.

[0070] Similar to the modeling method for positive deviations, the adjustment cost and amount of negative deviations can be obtained as follows:

[0071] (6)

[0072] (7)

[0073] (8)

[0074] Therefore, the output adjustment cost of unit i at time t can be obtained as follows:

[0075] (9)

[0076] The constraints of the inter-provincial reserve market clearing verification model in step S2 include provincial power generation and consumption balance constraints, provincial sub-balance constraints, unit operation constraints, unit group constraints, network security constraints, and practicality constraints.

[0077] The provincial power generation and consumption balance constraint is as follows:

[0078] (10)

[0079] In the formula: For the unit Time period Output, decision variable; For provincial power grid Unit assembly; for Provincial power grid The system load; for Provincial power grid The port plan, constant; , They represent provincial power grids respectively. Time period The incremental input and output are decision variables.

[0080] Since the directly dispatched generating units of the regional power grid do not directly participate in the provincial power generation and consumption balance, but rather their output is added to the inter-provincial power grid supply plan, adjusting the output of the directly dispatched generating units of the regional power grid is equivalent to modifying the inter-provincial power grid supply plan. In order to ensure that the inter-provincial power grid supply plan remains unchanged, a provincial power grid supply balance constraint is introduced, the specific expression of which is as follows:

[0081] (11)

[0082] In the formula: Provincial cross-section Time period The change in tidal current (the change relative to the initial tidal current). Indicates that the sending end is a province The inter-provincial section; This indicates that the receiving end is a provincial power grid. The inter-provincial section; , They represent provincial power grids respectively. Time period The increase in input and output.

[0083] The unit operation constraints include upper and lower limits of unit output, maximum number of start-ups and shutdowns, minimum start-up and shutdown time, and unit ramp-up and ramp-down constraints.

[0084] The upper and lower limits of the unit's output are constrained as follows:

[0085] (12)

[0086] in: Indicates the unit During the period The operating status is a 0 / 1 variable; if the unit is in a stopped state, then... This constraint can limit the unit's output to 0; if the unit is running, then... This constraint is a conventional upper and lower limit constraint for output. , They are the generator sets exist Maximum and minimum output during a given time period.

[0087] The maximum number of start-ups and shutdowns of the unit is constrained as follows:

[0088] (13)

[0089] in, , The units Maximum number of starts and stops; For the unit exist Whether the time period has switched to the startup state is a 0 / 1 variable, where 0 represents no startup switching and 1 represents startup switching; Indicates the unit exist Whether the time period is switched to the shutdown state is a 0 / 1 variable, where 0 represents no shutdown switch and 1 represents a shutdown switch.

[0090] The minimum start-up and shutdown time constraints for the unit are:

[0091] (14)

[0092] (15)

[0093] in, , These are the minimum continuous start-up time and minimum continuous shutdown time of the unit. Indicates the unit During the period The running status.

[0094] The unit's ramp-up and landslide constraints are:

[0095] (16)

[0096] (17)

[0097] in, For the unit Maximum uphill speed, For the unit Maximum downhill / climbing speed It is a generator set exist The output during a specific period.

[0098] Unit group constraints include unit group output constraints and unit group power constraints;

[0099] The output constraints of the unit group are:

[0100] (18)

[0101] in, , For unit group j, the maximum and minimum outputs are given during time period t.

[0102] The power constraints for the unit group are:

[0103] (19)

[0104] in, This represents the upper limit of the electricity consumption of unit group j on the clearing day.

[0105] The network security constraints include line power flow constraints and cross-sectional power flow constraints.

[0106] The power flow constraint of the line is:

[0107] (20)

[0108] in, For the line The limits of current transmission; For the unit The node is connected to the line The generator output power transfer distribution factor; For connecting lines The node is connected to the line The output power transfer distribution factor; The number of nodes in the system; For nodes For the line The output power transfer distribution factor; For nodes exist Bus load value for the specified time period; Indicates the contact line

[0109] The cross-sectional power flow constraint is:

[0110] (twenty one)

[0111] in, , Cross-sections The minimum and maximum transmission limits of the power flow; For the unit The node is located on the cross section The generator output power transfer distribution factor; For connecting lines The node is located on the cross section The output power transfer distribution factor; For nodes cross section The output power transfer distribution factor; For nodes exist Bus load value for the specified time period; Indicates the contact line .

[0112] The practical constraints include fixed output constraints of the unit and fixed start-stop mode constraints of the unit.

[0113] The fixed output constraint of the unit is:

[0114] (twenty two)

[0115] In the formula: Indicates the unit Time period The output setting value.

[0116] The fixed start-stop mode constraint for the unit is as follows:

[0117] (twenty three)

[0118] In the formula: Indicates the unit Time period The start / stop mode setting (run or stop).

[0119] Step S4, based on the calculation scenario constructed in Step S1, sets the optimization time period granularity (time period granularity 15 minutes, 96 time periods per day) and decision variables (power output of thermal power units) of the verification model in Step S2. Based on the start-up and shutdown result status of the gas turbine at the hourly granularity in Step S3, the start-up and shutdown status at the 15-minute granularity is fixed. The above inter-provincial reserve market clearing verification model is then solved to obtain the 15-minute granularity power output plan, cross-section / branch and equipment power flow of gas turbine and thermal power.

[0120] Step S5, based on the power flow and limits of the cross-section, branch, and equipment calculated in step S4, determines whether there are any cross-sections, branches, or equipment exceeding the limits. If the limits are exceeded, it indicates that the inter-provincial reserve market clearing result is unreasonable and needs to be cleared again; if the limits are not exceeded, it indicates that the inter-provincial reserve market clearing result is executable and is issued to each provincial power grid for tracking and implementation.

[0121] Step S6 outputs the gas turbine start-up and shutdown status calculated in step S3, and the unit output, cross-sectional / equipment / branch power flow and clearing result feasibility information calculated in step S4, and sends them to the inter-provincial backup auxiliary service technical support system.

[0122] Corresponding to the two-step optimization method for inter-provincial reserve market clearing verification provided in the above embodiments,

[0123] This invention also provides a two-step optimization device adapted to the clearing verification of the inter-provincial reserve market, including: a data acquisition module, a model building module, a first optimization solution module, a second optimization solution module, and a clearing result determination module;

[0124] The data acquisition module is used to acquire data on the inter-provincial reserve market clearing verification scenario;

[0125] The model building module is used to build an inter-provincial reserve market clearing verification model;

[0126] The first optimization solution module is used to set the first time period granularity and the first step optimization decision variables of the verification model based on the scenario data, and perform the first step safety constraint unit combination optimization solution on the inter-provincial standby market clearing verification model to obtain the gas turbine first time period granularity start-up and shutdown status.

[0127] The second optimization solution module is used to set the second time period granularity of the verification model and the decision variables of the second optimization step, and fix the start-up and shutdown status of the second time period granularity based on the start-up and shutdown status of the gas turbine in the first time period granularity; and perform the second step of safety constraint unit combination optimization solution on the inter-provincial reserve market clearing verification model to obtain the cross section, branch and equipment power flow.

[0128] The clearing result determination module is used to determine whether there are any sections, branches, or equipment exceeding the limits. If there are any sections, branches, or equipment exceeding the limits, clearing needs to be done again. Otherwise, it indicates that the clearing result of the inter-provincial standby market can be executed.

[0129] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working process of each module in the system and device described above can be referred to the corresponding process in the foregoing method embodiments, and will not be repeated here.

[0130] The method of this invention is applicable to the security verification of the clearing results of the inter-provincial reserve market in regional power grids, and features high computational efficiency and strong adaptability. The technical solution of this invention has been applied in the East China branch center, and the application effect meets expectations. The above description is only a preferred embodiment of this invention. It should be noted that for those skilled in the art, several improvements and modifications can be made without departing from the technical principles of this invention, and these improvements and modifications should also be considered within the scope of protection of this invention.

[0131] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0132] This application is described with reference to flowchart illustrations of methods, apparatus (systems), and computer program products according to embodiments of this application. It should be understood that each step in the flowchart can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the processes. Figure 1 A device for a function specified in one or more processes.

[0133] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 The function specified in one or more processes.

[0134] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 Steps of a specified function in one or more processes.

[0135] The embodiments of the present invention have been described above with reference to the accompanying drawings. However, the present invention is not limited to the specific embodiments described above. The specific embodiments described above are merely illustrative and not restrictive. Those skilled in the art can make many other forms under the guidance of the present invention without departing from the spirit and scope of the claims. All of these forms are within the protection scope of the present invention.

Claims

1. A two-step optimization method adapted to the clearing and verification of the inter-provincial reserve market, characterized in that, Includes the following steps: Acquire inter-provincial reserve market clearing verification scenario data; wherein, the inter-provincial reserve market clearing verification scenario data includes: system data, unit data, tie line plan data, load data, unit group data, and sensitivity data; the sensitivity data in the scenario data is calculated using the PQ decoupling method; Establish a verification model for the clearing out of the inter-provincial reserve market; The objective function of the inter-provincial reserve market clearing verification model is expressed as follows: ， In the formula: Indicates the total number of generating units; Indicates the total number of time periods; The cost of the output deviation of unit i at time t; Indicates provincial power grid Time period The incremental amount received, Indicates provincial power grid Time period The incremental amount of data sent out and For decision variables; This represents the penalty factor used to optimize network flow constraints in line l during market clearing. , These represent the forward and reverse power flow relaxation variables of line l, respectively. Total number of lines; The penalty factor represents the network flow constraint used for market clearing optimization section s; , Let S represent the forward and reverse tidal current relaxation variables of section s, respectively. Indicates the total number of cross-sections. This indicates the penalty cost for the increased power transmission from the provincial power grid; The constraints of the inter-provincial reserve market clearing verification model include provincial power generation and consumption balance constraints, provincial gate balance constraints, unit operation constraints, unit group constraints, network security constraints, and practical application constraints. The provincial power generation and consumption balance constraints are expressed as follows: ， In the formula: For the unit Time period Effort output is a decision variable; For provincial power grid Unit assembly; for Provincial power grid The system load; for Provincial power grid The port number is a constant; The provincial-level balance constraints are expressed as follows: ， In the formula: Provincial cross-section Time period The change in tidal current relative to the initial tidal current; This indicates that the sending end is a provincial power grid. The inter-provincial cross-section; This indicates that the receiving end is a provincial power grid. The inter-provincial cross-section; Indicates provincial power grid Generator set assembly; Based on the scenario data, the first time period granularity and the first step optimization decision variables of the verification model are set, and the first step safety constraint unit combination optimization solution is performed on the inter-provincial standby market clearing verification model to obtain the gas turbine first time period granularity start-up and shutdown status. The second time period granularity of the verification model and the decision variables for the second optimization step are set. The granularity of the second time period is smaller than that of the first time period. The start-up and shutdown status of the gas turbine is fixed according to the start-up and shutdown status of the gas turbine in the first time period. Specifically, the granularity of the first time period of the verification model is set to 1 hour, and the granularity of the second time period of the verification model is set to 15 minutes. The second step of the safety constraint economic scheduling optimization solution is performed on the inter-provincial reserve market clearing verification model to obtain the cross section, branch, and equipment power flow. Determine if there are any sections, branches, or equipment exceeding the limits. If so, a new clearing process is required. Otherwise, it indicates that the clearing results of the inter-provincial standby market can be implemented.

2. The two-step optimization method for inter-provincial reserve market clearing verification according to claim 1, characterized in that, The unit operation constraints include upper and lower limits of unit output, maximum number of unit start-ups and shutdowns, minimum start-up and shutdown times, and unit ramp-up and ramp-down constraints; the unit group constraints include unit group output constraints and unit group power constraints; the network security constraints include line power flow constraints and cross-sectional power flow constraints; and the practical constraints include fixed unit output constraints and fixed unit start-up and shutdown methods constraints.

3. The two-step optimization method for inter-provincial reserve market clearing verification according to claim 1, characterized in that, Cost of output deviation of unit i at time t It is expressed as follows: ， in For positive deviation adjustment costs, Adjust costs for negative deviations.

4. The two-step optimization method for adaptive reserve market clearing verification according to claim 1, characterized in that, The results obtained from the first step of the safety constraint unit combination optimization solution also include the output of the thermal power unit; the second step of the safety constraint economic dispatch optimization solution, in addition to obtaining the cross section, branch and equipment power flow, also obtains the second-granularity gas turbine start-up and shutdown status and the output of the thermal power unit.

5. A two-step optimization device adapted to the clearing and verification of the inter-provincial reserve market, characterized in that, include: The system includes a data acquisition module, a model building module, a first optimization solution module, a second optimization solution module, and a clearing result determination module. The data acquisition module is used to acquire inter-provincial reserve market clearing verification scenario data; wherein, the inter-provincial reserve market clearing verification scenario data includes: system data, unit data, tie line plan data, load data, unit group data, and sensitivity data; the sensitivity data in the scenario data is calculated using the PQ decoupling method; The model building module is used to build an inter-provincial reserve market clearing verification model; The objective function of the inter-provincial reserve market clearing verification model is expressed as follows: ， In the formula: Indicates the total number of generating units; Indicates the total number of time periods; The cost of the output deviation of unit i at time t; Indicates provincial power grid Time period The incremental amount received, Indicates provincial power grid Time period The incremental amount of data sent out and For decision variables; This represents the penalty factor used to optimize network flow constraints in line l during market clearing. , These represent the forward and reverse power flow relaxation variables of line l, respectively. Total number of lines; The penalty factor represents the network flow constraint used for market clearing optimization section s; , Let S represent the forward and reverse tidal current relaxation variables of section s, respectively. Indicates the total number of cross-sections. This indicates the penalty cost for the increased power transmission from the provincial power grid; The constraints of the inter-provincial reserve market clearing verification model include provincial power generation and consumption balance constraints, provincial gate balance constraints, unit operation constraints, unit group constraints, network security constraints, and practical application constraints. The provincial power generation and consumption balance constraints are expressed as follows: ， In the formula: For the unit Time period Effort output is a decision variable; For provincial power grid Unit assembly; for Provincial power grid The system load; for Provincial power grid The port number is a constant; The provincial-level balance constraints are expressed as follows: ， In the formula: Provincial cross-section Time period The change in tidal current relative to the initial tidal current; This indicates that the sending end is a provincial power grid. The inter-provincial cross-section; This indicates that the receiving end is a provincial power grid. The inter-provincial cross-section; Indicates provincial power grid Generator set assembly; The first optimization solution module is used to set the first time period granularity and the first step optimization decision variables of the verification model based on the scenario data, and perform the first step safety constraint unit combination optimization solution on the inter-provincial standby market clearing verification model to obtain the gas turbine first time period granularity start-up and shutdown status. The second optimization solution module is used to set the second time period granularity of the verification model and the decision variables of the second optimization step. The granularity of the second time period is smaller than that of the first time period. The start-up and shutdown status of the gas turbine is fixed according to the start-up and shutdown status of the gas turbine in the first time period. The second step of safety constraint economic dispatch optimization solution is performed on the inter-provincial reserve market clearing verification model to obtain the cross section, branch and equipment power flow. The first time period granularity of the verification model is set to 1 hour, and the second time period granularity of the verification model is set to 15 minutes. The clearing result determination module is used to determine whether there are any sections, branches, or equipment exceeding the limits. If there are any sections, branches, or equipment exceeding the limits, clearing needs to be done again. Otherwise, it indicates that the clearing result of the inter-provincial standby market can be executed.

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