A wind-solar-hydro-pumped storage joint regulation method based on mixed integer programming

Abstract

This invention specifically discloses a wind-solar-hydro-pumped storage joint control method based on mixed integer programming, belonging to the field of power grid dispatching technology. The method comprises the following steps: the power grid dispatching center predicts the regional load curve for the next day and arranges the output of the consortium; wind and solar power plants within the consortium generate wind and solar output prediction curves for the next day's 96-hour period; the consortium comprehensively considers electricity prices, pumped storage operating costs, and performance penalties to optimize the output scheme and declare its proportion of system load; a joint optimization model is established, setting constraints such as reservoir capacity, pumping, and power generation inequalities and equality conditions for pumped storage units; and mixed integer linear programming (MILP) is used to solve for and generate the optimal dispatch scheme. This method can effectively mitigate the uncertainties of wind and solar power, improve energy utilization, increase system output stability and power quality, and maximize the economic benefits of the consortium.

Description

Technical Field

[0001] This invention relates to the field of power grid dispatching technology, and in particular to a wind-solar-hydro-pumped storage joint control method based on mixed integer programming. Background Technology

[0002] The penetration rate of renewable energy sources, such as wind and solar power, in the power system continues to increase, becoming a core force in energy transformation. However, the inherent non-steady-state characteristics of these clean energy sources lead to a significant spatiotemporal mismatch between their output curves and grid load demand. This mismatch poses a severe challenge to the frequency stability and power balance of the power grid, necessitating efficient solutions to ensure the safe and reliable operation of the power system.

[0003] Against this backdrop, building energy storage systems with flexible adjustment capabilities has become a key measure for stabilizing power grid operation, and is hailed as the "ballast" for grid stability. Among them, pumped storage technology, with its unique dual-mode operation of power generation and pumping and its large-capacity energy storage advantages, has demonstrated irreplaceable value in mitigating fluctuations in renewable energy output. This technology can effectively cope with power fluctuations ranging from minutes to hours by quickly switching between power generation and pumping modes, providing the power grid with flexible peak-shaving and frequency regulation services.

[0004] Energy storage technology has been proven in practice to be one of the most effective means to solve the problem of fluctuating wind and solar power output. Pumped hydro storage, as the most economical and mature high-quality energy storage power source, is an ideal choice for participating in the joint regulation of wind, solar, and thermal power. In the wind-solar-thermal-pumped storage joint operation system, how to achieve the rational configuration of each energy unit and promote the coordinated linkage and joint regulation of pumped hydro storage with various power sources, thereby minimizing the uncertainty of wind and solar power output, has become the core research topic in this field, highlighting the importance and urgency of joint regulation methods.

[0005] Current research largely focuses on improving the integration rate of wind and solar energy, while research on how to fully leverage the overall advantages of pumped storage systems and optimize their operation is relatively insufficient. Jointly regulating the wind-solar-thermal-pumped storage system as an organic whole to achieve multi-energy synergistic optimization is a key challenge that urgently needs attention and resolution, and is of great significance for promoting energy transformation and building a new power system. Summary of the Invention

[0006] The purpose of this invention is to propose a wind-solar-hydro-pumped storage joint regulation method based on mixed integer programming, which, while absorbing wind and solar power output, ensures that the joint operation system matches the system load demand and maximizes economic benefits.

[0007] To achieve the above objectives, this invention proposes a wind-solar-hydro-pumped storage joint regulation method based on mixed integer programming. By predicting the wind and solar power output for the following day, advance scheduling of pumped storage start-up and shutdown is performed. Based on the mixed integer programming algorithm, the maximum benefit is found while meeting the system output requirements. The specific steps are as follows:

[0008] Step S1: The power grid dispatch center predicts the regional load curve for the next day based on historical load demand and arranges the output of the regional wind-solar-hydro-storage power station complex.

[0009] Step S2: Based on meteorological parameters and unit characteristics, the wind-solar power plants within the consortium predict the output curves of the local wind-solar-hydro-storage power station and the photovoltaic power station every 15 minutes the next day using historical data, generating the wind and solar output prediction curves for 96 time periods the next day.

[0010] Step S3: The wind-solar-hydro-storage power station consortium comprehensively considers the electricity price curve, the operating cost of pumped storage units, and relevant factors such as assessment penalties, optimizes the power output plan, and reports to the dispatch center the proportion of the power output to the system load for the next day.

[0011] Step S4: Establish a joint optimization model of wind-solar-hydro-storage and set constraints for pumped storage units, including reservoir capacity constraints, inequality constraints between pumping and power generation, and equality constraints between pumping and power generation.

[0012] Step S5: Solve using Mixed Integer Linear Programming (MILP) to generate the optimal scheduling scheme.

[0013] Preferably, the operation method includes day-ahead forecasting, intraday rapid dispatching, calculation of penalty costs, and calculation of maximum benefit; wherein, day-ahead forecasting utilizes historical and empirical algorithms, intraday rapid dispatching is achieved through advance calculation, penalty costs take into account the actual situation of the power grid receiving electricity, and maximum benefit is determined by the objective function to determine the joint operation mode.

[0014] Preferably, in step S2, the meteorological parameters include wind speed, wind direction, air pressure, air temperature, light intensity, and sunshine duration.

[0015] Preferably, in step S3, the wind-solar-hydro-storage consortium constructs a multi-dimensional collaborative optimization model by integrating electricity market signals, energy storage system operating characteristics, and dispatch assessment mechanisms; guided by time-of-use electricity price fluctuations, it comprehensively considers the energy consumption costs of pumped storage units in different operating condition transitions, while using the power deviation penalty mechanism as a risk constraint, and finally generates a power output application scheme that dynamically matches the grid load curve.

[0016] In the scheduling and operation of the wind-solar-hydro-storage multi-energy complex, its declared power output curve follows a rigid coupling constraint—that is, the proportion of the declared power output to the system load for each time period on the following day.α To maintain a constant level, it is mandatory that the total output of the consortium and the system load curve form a strictly synchronous mapping relationship;

[0017] The dynamic deviation between the actual operating power and the declared value will trigger the power deviation penalty mechanism. If the output deviates, the consortium will be given a corresponding output deviation penalty.

[0018] Preferably, in step S4, a joint optimization model of wind-solar-hydro-storage is established, and the steps are as follows:

[0019] Step S411: Taking the maximization of the benefits of the wind-solar-hydro-storage integrated operation as the objective, and combining the start-up and shutdown costs of pumped storage power stations with the penalty for deviating from the output plan, an objective function is established, and the calculation formula is as follows:

[0020] ;

[0021] in, This represents a time series, with each 15-minute interval dividing a day into 24 hours and 96 intervals. ; for The on-grid electricity price for different time periods is divided into peak-hour electricity price and off-peak-hour electricity price. for Total output of pumped storage power station generator units during the period; for Wind turbine output during specific time periods; for Photovoltaic unit output during certain periods; for The output of the hydropower unit during the specified period; p k for Total pumping power of pumps in pumped storage power stations during specific time periods; and Costs for starting / stopping the water pump; and The number of water pump units started / stopped during time period k; c This is the penalty coefficient for deviation in output force; L k for k The planned output of the wind-solar-hydro-storage power grid complex during a given period; in the objective function, the first term represents the revenue from selling net on-grid electricity; the second and third terms represent the costs of starting / stopping pumped storage units; and the fourth term represents the penalty for deviating from the planned output.

[0022] Step S412: Calculate the planned output of the wind-solar-hydro-storage complex, using the following formula:

[0023] ;

[0024] in, For the predicted output of wind turbines during time period k; Predicted output of the photovoltaic generator during time period k; L sk for k Total load of the system during the time period.

[0025] Preferably, in step S4, based on the operating conditions of the wind-solar-hydro-storage complex, a reservoir capacity constraint is set for the pumped storage unit, as shown in the following formula:

[0026] ;

[0027] ;

[0028] ;

[0029] ;

[0030] in, , These are the minimum and maximum reservoir capacities, respectively. , These are the minimum and maximum reservoir capacities of the upper and lower reservoirs, respectively. and for k The actual reservoir capacity at the upstream and downstream points during the specified time period; and This represents the initial storage capacity of the upper and lower reservoirs. and This refers to the final storage capacity of the upper and lower reservoirs. δ min and δ max This represents the minimum and maximum changes in storage capacity at the beginning and end of each day.

[0031] Preferably, in step S4, inequality constraints are applied to the pumped storage unit regarding pumping and power generation, as follows:

[0032] Step S421, Set pump unit operating constraints: In k The total number of pumps operating during a given period must be less than the total number of pumped storage units, as shown in the following formula:

[0033] ;

[0034] in, for k The total number of water pumps operating during a given time period N This represents the total number of reversible pumped-generator units in a pumped-storage power station.

[0035] Step S422, Design power constraints for the water pump unit: In k During a given time period, the power of the water pumps operating must not exceed the maximum power of the number of pumps operating during that time period, nor should it be lower than the minimum power of the number of pumps operating during that time period, as shown in the following formula:

[0036] ;

[0037] in, and These are the maximum and minimum pumping power of a single water pump, respectively.

[0038] Step S423, Design power constraints for generator sets: In k During a given period, the pumped-storage generator unit's power output must be between its minimum power output and the maximum power output of all units operating under the same power generation condition, as shown in the following formula:

[0039] ；

[0040] in, , These are the upper and lower limits of the output of pumped storage units, respectively.

[0041] Step S424: Design output deviation constraints: to ensure that the final output tracks the planned output. The formula is as follows:

[0042] ;

[0043] in, This is the deviation coefficient between the total output and load of the final combined system;

[0044] Step S425: Constrain the total number of start-ups and shutdowns of the pump units in the pumped storage power station, using the following formula:

[0045] ;

[0046] in, , They are respectively k The number of times the program starts and stops during a given time period.

[0047] Preferably, in step S4, the pumped storage unit is subjected to equation constraints for pumping and power generation, as follows:

[0048] Step S431: Design the constraint for changes in storage capacity, using the following formula:

[0049] ;

[0050] ;

[0051] in, for k The water head of the reservoir during the period , These are the downward discharge flow rate functions with pumping power and head as independent variables, respectively. , They are respectively k -1 The actual reservoir capacity of the upper and lower reservoirs during the time period;

[0052] Step S432: Based on the transformation constraint of the number of pumping units in adjacent time periods, deduce that the number of pumping units operating in the next time period is equal to the number of pumping units in the previous time period plus the number of units started minus the number of units shut down, as shown in the following formula:

[0053] ;

[0054] in, for k The total number of water pumps operating during the +1 time period for k The number of pumping units started during the +1 time period for k +1 Number of pumping units shut down during the time period.

[0055] Preferably, in step S5, the steps for solving mixed-integer linear programming (MILP) include:

[0056] Step S51: Data preparation, including time segmentation, efficiency parameters, and cost coefficients;

[0057] Step S52: Define the optimization problem, including the objective function and continuous / integer variables;

[0058] Step S53: Construct linear and logical constraints;

[0059] Step S54: Select the solver and set the options;

[0060] Step S55: Solve the optimization problem and verify whether the solution satisfies the constraints;

[0061] Step S56: Output the optimal unit output scheme.

[0062] Therefore, this invention proposes a wind-solar-hydro-pumped storage joint regulation method based on mixed integer programming, the beneficial effects of which are as follows:

[0063] (1) Based on the mixed integer programming method, a wind-solar-hydro-pumped storage joint operation mode is constructed by predicting the day-ahead wind and solar power output and scheduling the start and stop of pumped storage. The objective function is to maximize the benefits of the joint operation mode while meeting the system output requirements.

[0064] (2) This invention achieves the maximum utilization of wind power and photovoltaic power while tracking load demand output, avoiding the serious wind and solar curtailment phenomenon of traditional systems, greatly improving energy utilization, and thus being able to actively respond to the rapid changes of wind and solar power.

[0065] (3) This invention increases the stability of system output and power quality, provides strong support for the widespread access of new energy to the power system, and finds the most efficient operating mode for the joint venture power station, which helps the system to operate for a long time and improves reliability and economy.

[0066] The technical solution of the present invention will be further described in detail below with reference to the accompanying drawings and embodiments. Attached Figure Description

[0067] Figure 1 This is a diagram of the power output scheduling model of the wind-solar-hydro-storage power station complex of the present invention;

[0068] Figure 2 This is a flowchart of the mixed integer programming solution of the present invention;

[0069] Figure 3 This is a wind turbine output curve diagram for a certain region in an embodiment of the present invention;

[0070] Figure 4 This is a photovoltaic power generation curve of a certain region in an embodiment of the present invention;

[0071] Figure 5 This is a graph showing the power generation curve of a small hydropower station in a certain region, as described in an embodiment of the present invention.

[0072] Figure 6 This is a load curve diagram of a certain region in an embodiment of the present invention;

[0073] Figure 7 This is a graph showing the output of each power source versus the pumping load when the pumped storage unit's dispatch output deviation coefficient is 5% in this embodiment of the invention.

[0074] Figure 8 This is a curve showing the combined output tracking and deviation range when the pumped-storage unit dispatch output deviation coefficient is 5% in an embodiment of the present invention.

[0075] Figure 9 This is a graph showing the output of each power source versus the pumping load when the pumped storage unit's dispatch output deviation coefficient is 2% in this embodiment of the invention.

[0076] Figure 10 This is a curve showing the combined output tracking and deviation range when the pumped storage unit scheduling output deviation coefficient is 2% in an embodiment of the present invention. Detailed Implementation

[0077] To make the technical solutions, advantages, and objectives of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below. The described embodiments are only some, not all, of the embodiments of the present invention. All other embodiments obtained by those skilled in the art based on the described embodiments of the present invention without creative effort are within the protection scope of the present invention.

[0078] Unless otherwise defined, the technical or scientific terms used in this invention shall have the ordinary meaning as understood by one of ordinary skill in the art to which this invention pertains.

[0079] like Figure 1 The diagram shown illustrates the power output scheduling model of the wind-solar-hydro-storage power station complex of this invention. By predicting the wind and solar power output for the following day, advance scheduling of pumped storage start-up and shutdown is performed. Based on a mixed integer programming algorithm, the maximum benefit is found while meeting the system's power output requirements. The specific steps are as follows:

[0080] S1. The power grid dispatch center predicts the regional load curve for the next day based on historical load demand and arranges the output of the regional wind-solar-hydro-storage power station complex.

[0081] S2. Based on meteorological parameters (wind speed, wind direction, air pressure, temperature, light intensity and sunshine duration) and unit characteristics, the wind-solar-hydro-storage power plants within the consortium predict the output curves of the local wind power stations and photovoltaic power stations every 15 minutes the next day through historical data, generating wind and solar output prediction curves for 96 time periods the next day.

[0082] S3, the wind-solar-hydro-storage power station consortium comprehensively considers the electricity price curve, the operating cost of pumped storage units and relevant factors such as assessment and penalties, optimizes the power output plan, and reports to the dispatch center the proportion of the power output to the system load for the next day;

[0083] The wind-solar-hydro-storage consortium integrates electricity market signals, energy storage system operating characteristics, and dispatch assessment mechanisms to construct a multi-dimensional collaborative optimization model. Guided by time-of-use electricity price fluctuations, it comprehensively considers the energy consumption costs of pumped storage units during different operating conditions, while using power deviation penalty mechanisms as risk constraints, ultimately generating a power output application scheme that dynamically matches the grid load curve.

[0084] In the scheduling and operation of the wind-solar-hydro-storage multi-energy complex, its declared power output curve follows a rigid coupling constraint—that is, the proportion of the declared power output to the system load for each time period on the following day. α To maintain a constant level, it is mandatory that the total output of the consortium and the system load curve form a strictly synchronous mapping relationship;

[0085] The dynamic deviation between the actual operating power and the declared value will trigger a power deviation penalty mechanism. If the output deviates, the consortium will be given a corresponding output deviation penalty.

[0086] S4. Establish a joint optimization model of wind-solar-hydro-storage and set constraints for pumped storage units, including reservoir capacity constraints, inequality constraints between pumping and power generation, and equality constraints between pumping and power generation.

[0087] The steps for establishing a joint optimization model for wind-solar-hydro-storage are as follows:

[0088] S411. Taking the maximization of the benefits of the wind-solar-hydro-storage integrated operation as the objective, and combining the start-up and shutdown costs and the penalty for deviating from the output plan in pumped storage power stations, an objective function is established, and the calculation formula is as follows:

[0089] ;

[0090] in, Representing a time series, ; for The on-grid electricity price for a given time period; for Total output of pumped storage power station generator units during specific periods; for Wind turbine output during specific time periods; for Photovoltaic unit output during certain periods; for The output of the hydropower unit during the specified period; p k for Total pumping power of pumps in pumped storage power stations during specific time periods; and Costs for starting / stopping the water pump; and For time period k, the number of water pump units started / stopped. c This is the penalty coefficient for deviation in output force; L k for Planned output of the wind-solar-hydro-storage power station complex during certain periods;

[0091] S412. Calculate the planned output of the wind-solar-hydro-storage complex using the following formula:

[0092] ;

[0093] in, For the predicted output of wind turbines during time period k; Predicted output of the photovoltaic generator during time period k; L sk for Total load of the system during the time period.

[0094] Based on the operating conditions of the wind-solar-hydro-storage complex, the reservoir capacity constraint for pumped storage units is set as follows:

[0095] ;

[0096] ;

[0097] ;

[0098] ;

[0099] in, , These are the minimum and maximum reservoir capacities, respectively. , These are the minimum and maximum reservoir capacities of the upper and lower reservoirs, respectively. and for k The actual reservoir capacity at the upstream and downstream points during the specified time period; and This represents the initial storage capacity of the upper and lower reservoirs. and This refers to the final storage capacity of the upper and lower reservoirs. δ min and δ max This represents the minimum and maximum changes in storage capacity at the beginning and end of each day.

[0100] Based on the operating conditions of the wind-solar-hydro-storage complex, the inequality constraints for pumped storage units regarding pumping and power generation are applied as follows:

[0101] S421. Set operating constraints for the pumping unit: In k The total number of pumps operating during a given period must be less than the total number of pumped storage units, as shown in the following formula:

[0102] ;

[0103] in, for k The total number of water pumps operating during a given time period N This represents the total number of reversible pumped-generator units in a pumped-storage power station.

[0104] S422. Design power constraints for water pump units: In k During a given time period, the power of the water pumps operating must not exceed the maximum power of the number of pumps operating during that time period, nor should it be lower than the minimum power of the number of pumps operating during that time period, as shown in the following formula:

[0105] ;

[0106] in, and These are the maximum and minimum pumping power of a single water pump, respectively.

[0107] S423. Design constraints on generator set power: In k During a given period, the pumped-storage generator unit's power output must be between its minimum power output and the maximum power output of all units operating under the same power generation condition, as shown in the following formula:

[0108] ；

[0109] in, , These are the upper and lower limits of the output of pumped storage units, respectively.

[0110] S424. Design output deviation constraint: to ensure that the final output achieves the effect of tracking the planned output, the formula is as follows:

[0111] ;

[0112] in, This is the deviation coefficient between the total output and load of the final combined system;

[0113] S425. A constraint is imposed on the total number of start-ups and shutdowns of the pump units in a pumped storage power station, using the following formula:

[0114] ;

[0115] in, , They are respectively k The number of times the program starts and stops during a given time period.

[0116] Based on the operating conditions of the wind-solar-hydro-storage complex, the equation constraints for pumped storage units regarding pumping and power generation are applied as follows:

[0117] S431. Design constraints for changes in warehouse capacity, using the following formula:

[0118] ;

[0119] ;

[0120] in, for k The water head of the reservoir during the period , These are the downward discharge flow rate functions with pumping power and head as independent variables, respectively. , They are respectively The actual reservoir capacity at the upstream and downstream points during the specified time period;

[0121] S432. Based on the transformation constraint of the number of pumping units in adjacent time periods, it is deduced that the number of pumping units operating in the next time period is equal to the number of pumping units in the previous time period plus the number of units started minus the number of units shut down, as shown in the following formula:

[0122] ;

[0123] in, for The total number of water pumps operating during a given time period for The number of pumping units started during a given time period. for Number of pumping units shut down during specific time periods.

[0124] S5. Solve using mixed integer linear programming (MILP) to generate the optimal scheduling scheme.

[0125] like Figure 2 As shown, the steps for solving mixed-integer linear programming (MILP) include:

[0126] S51. Data preparation, including time segmentation, efficiency parameters, and cost coefficients;

[0127] S52. Define the optimization problem, including the objective function and continuous / integer variables;

[0128] S53. Construct linear and logical constraints;

[0129] S54. Select the solver and set the options;

[0130] S55. Solve the optimization problem and verify whether the solution satisfies the constraints;

[0131] S56, Output the optimal unit output scheme.

[0132] The invention will be further illustrated below with specific examples.

[0133] Taking a certain region as an example, simulation verification was conducted on the MATLAB R2023b platform. 96 time periods were formed with 15-minute intervals. The total installed capacity of the hydropower units was 300MW, and the number of pumped-storage units was 10. Two schemes were set up for comparison:

[0134] Option 1: Use pumped-storage units to schedule output deviation coefficient of 5%;

[0135] Option 2: Use pumped-storage units to schedule output deviation coefficient of 2%;

[0136] 1. Parameter settings.

[0137] 1.1 Basic parameters of pumped storage are shown in Table 1 and Table 2.

[0138] Table 1 Power Generation Parameter Settings

[0139] ;

[0140] Table 2 Pumping Parameter Settings

[0141] ;

[0142] 1.2. Constraint parameter settings are shown in Table 3.

[0143] Table 3 Constraint Parameter Settings

[0144] ;

[0145] 1.3 Calculate wind power output, photovoltaic power output, small hydropower station output and load demand.

[0146] according to Figure 1 The scheduling model shown yields wind power, solar power, and load demand curves, as follows: Figures 3-6 As shown.

[0147] 2. Results Analysis.

[0148] Option 1: Use pumped storage units to schedule output deviation coefficient of 5%.

[0149] (1) Scheduling situation

[0150] Based on the mixed integer algorithm and using the Intlinprog solver, the results of the joint scheduling and operation of wind-solar-hydro-storage can be obtained, such as... Figure 7-8 As shown.

[0151] from Figure 7-8 It can be concluded that when wind, solar and hydropower can meet the demand, pumped storage mainly operates in pumping mode, consuming the overflow of electricity. However, when the load demand is relatively large, pumped storage acts as a fourth energy source to continue to supplement power generation, and mainly operates in power generation mode.

[0152] Option 2: Use pumped storage units to schedule output deviation coefficient of 2%.

[0153] (1) Scheduling situation

[0154] When the allowable deviation between the combined output and the planned output is set at 2%, the following is obtained: Figure 9-10 The solution results are as follows.

[0155] (2) Profit analysis.

[0156] Table 4. Comparison of Benefits between Option 1 and Option 2

[0157] ;

[0158] As shown in Table 4, although a deviation rate of 2% is better at tracking grid load requirements than a deviation rate of 5%, the net benefit of Option 1 is better. Therefore, determining the optimal deviation constraint should be based on the actual situation, the requirements of grid dispatch, and the benefits of the consortium.

[0159] It is worth noting that all contents not described in detail in this invention are existing technologies and are well known to those skilled in the art.

[0160] Therefore, this invention provides a wind-solar-hydro-pumped storage joint control method based on mixed integer programming, which can maximize the utilization of wind and solar power generation while tracking load demand, avoid the curtailment of wind and solar power in traditional systems, significantly improve energy utilization efficiency and respond to rapid changes in wind and solar power; by constructing optimization models and constraints, it increases the stability of system output and power quality, providing support for the widespread access of new energy sources; and by determining the joint operation mode with the goal of maximizing benefits, it achieves improvements in reliability and economy.

[0161] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and not to limit them. Although the present invention has been described in detail with reference to preferred embodiments, those skilled in the art should understand that modifications or equivalent substitutions can still be made to the technical solutions of the present invention, and these modifications or equivalent substitutions cannot cause the modified technical solutions to deviate from the spirit and scope of the technical solutions of the present invention.

Claims

1. A method for joint regulation of wind-solar-hydro-pumped storage based on mixed integer programming, characterized in that, By predicting the wind and solar power output for the following day in advance, the pumped storage hydroelectric power plant can be scheduled for start-up and shutdown in advance. Based on a mixed integer programming algorithm, the maximum benefit can be found while meeting the system's power output requirements. The specific steps are as follows: Step S1: The power grid dispatch center predicts the regional load curve for the next day based on historical load demand and arranges the output of the regional wind-solar-hydro-storage power station complex. Step S2: Based on meteorological parameters and unit characteristics, the wind-solar power plants within the consortium predict the output curves of the local wind-solar-hydro-storage power station and the photovoltaic power station every 15 minutes the next day using historical data, generating the wind and solar output prediction curves for 96 time periods the next day. Step S3: The wind-solar-hydro-storage power station consortium comprehensively considers the electricity price curve, the operating cost of pumped storage units, and relevant factors such as assessment penalties, optimizes the power output plan, and reports to the dispatch center the proportion of the power output to the system load for the next day. Step S4: Establish a joint optimization model of wind-solar-hydro-storage and set constraints for pumped storage units, including reservoir capacity constraints, inequality constraints between pumping and power generation, and equality constraints between pumping and power generation. Step S5: Solve using Mixed Integer Linear Programming (MILP) to generate the optimal scheduling scheme; In step S3, the wind-solar-hydro-storage consortium constructs a multi-dimensional collaborative optimization model by integrating electricity market signals, energy storage system operating characteristics, and dispatch assessment mechanisms. Guided by time-of-use electricity price fluctuations, it comprehensively considers the energy consumption costs of pumped storage units during different operating condition transitions, while using the power deviation penalty mechanism as a risk constraint, ultimately generating a power output application scheme that dynamically matches the grid load curve. In the scheduling and operation of the wind-solar-hydro-storage multi-energy complex, its declared power output curve follows a rigid coupling constraint—that is, the proportion of the declared power output to the system load for each time period on the following day. α To maintain a constant level, it is mandatory that the total output of the consortium and the system load curve form a strictly synchronous mapping relationship; The dynamic deviation between the actual operating power and the declared value will trigger the power deviation penalty mechanism. If the output deviates, the consortium will be given the corresponding output deviation penalty. In step S4, a joint optimization model of wind-solar-hydro-storage is established, and the steps are as follows: Step S411: Taking the maximization of the benefits of the wind-solar-hydro-storage integrated operation as the objective, and combining the start-up and shutdown costs of pumped storage power stations with the penalty for deviating from the output plan, an objective function is established, and the calculation formula is as follows: ； in, Representing a time series, =1,2,…,96; for The on-grid electricity price for a given time period; for Total output of pumped storage power station generator units during the period; for Wind turbine output during specific time periods; for Photovoltaic unit output during certain periods; for The output of the hydropower unit during the specified period; for Total pumping power of pumps in pumped storage power stations during specific time periods; and Costs for starting / stopping the water pump; and The number of water pump units started / stopped during time period k; This is the penalty coefficient for deviation in output force; for Planned output of the wind-solar-hydro-storage power station complex during certain periods; Step S412: Calculate the planned output of the wind-solar-hydro-storage complex, using the following formula: ； in, for Predicted output of wind turbines during specific time periods; for Predicted output of photovoltaic units during specific time periods; for Total load of the system during the time period.

2. The wind-solar-hydro-pumped storage joint regulation method based on mixed integer programming according to claim 1, characterized in that, The operation method includes day-ahead forecasting, intraday rapid dispatching, calculation of penalty costs, and calculation of maximum benefit. Among them, day-ahead forecasting utilizes historical and empirical algorithms, intraday rapid dispatching is achieved through advance calculation, penalty costs take into account the actual situation of the power grid receiving electricity, and maximum benefit is determined by the objective function to determine the joint operation mode.

3. The wind-solar-hydro-pumped storage joint regulation method based on mixed integer programming according to claim 1, characterized in that, In step S2, the meteorological parameters include wind speed, wind direction, air pressure, air temperature, light intensity, and sunshine duration.

4. The wind-solar-hydro-pumped storage joint regulation method based on mixed integer programming according to claim 1, characterized in that, In step S4, based on the operating conditions of the wind-solar-hydro-storage complex, reservoir capacity constraints are set for the pumped storage units, as shown in the following formula: ； ； ； ； in, , These are the minimum and maximum reservoir capacities, respectively. , These are the minimum and maximum reservoir capacities, respectively. and for The actual reservoir capacity at the upstream and downstream points during the specified time period; and This represents the initial storage capacity of the upper and lower reservoirs. and This refers to the final storage capacity of the upper and lower reservoirs. and This represents the minimum and maximum changes in reservoir capacity during the first and last periods of each day.

5. The wind-solar-hydro-pumped storage joint regulation method based on mixed integer programming according to claim 1, characterized in that, In step S4, inequality constraints are applied to the pumped storage unit for pumping and power generation, as follows: Step S421, Set pump unit operating constraints: In The total number of pumps operating during a given period must be less than the total number of pumped storage units, as shown in the following formula: ； in, for The total number of water pumps operating during a given time period N This represents the total number of reversible pumped-generator units in a pumped-storage power station. Step S422, Design power constraints for the water pump unit: In During a given time period, the power of the water pumps operating must not exceed the maximum power of the number of pumps operating during that time period, nor should it be lower than the minimum power of the number of pumps operating during that time period, as shown in the following formula: ； in, and These are the maximum and minimum pumping power of a single water pump, respectively. Step S423, Design power constraints for generator sets: In During a given period, the pumped-storage generator unit's power output must be between its minimum power output and the maximum power output of all units operating under the same power generation condition, as shown in the following formula: ； in, , These are the upper and lower limits of the output of pumped storage units, respectively. Step S424: Design output deviation constraints: to ensure that the final output tracks the planned output. The formula is as follows: ； in, This is the deviation coefficient between the total output and load of the final combined system; Step S425: Constrain the total number of start-ups and shutdowns of the pump units in the pumped storage power station, using the following formula: ； in, , They are respectively The number of times the program starts and stops during a given time period.

6. The wind-solar-hydro-pumped storage joint regulation method based on mixed integer programming according to claim 1, characterized in that, In step S4, the equation constraints for pumped storage units regarding pumping and power generation are applied, as follows: Step S431: Design the constraint for changes in storage capacity, using the following formula: ； ； in, for The water head of the reservoir during the period , These are the downward discharge flow rate functions with pumping power and head as independent variables, respectively. , They are respectively The actual reservoir capacity at the upstream and downstream points during the specified time period; Step S432: Based on the transformation constraint of the number of pumping units in adjacent time periods, deduce that the number of pumping units operating in the next time period is equal to the number of pumping units in the previous time period plus the number of units started minus the number of units shut down, as shown in the following formula: ； in, for The total number of water pumps operating during a given time period for The number of pumping units started during a given time period. for Number of pumping units shut down during specific time periods.

7. The wind-solar-hydro-pumped storage joint regulation method based on mixed integer programming according to claim 1, characterized in that, In step S5, the steps for solving mixed integer linear programming (MILP) include: Step S51: Data preparation, including time segmentation, efficiency parameters, and cost coefficients; Step S52: Define the optimization problem, including the objective function and continuous / integer variables; Step S53: Construct linear and logical constraints; Step S54: Select the solver and set the options; Step S55: Solve the optimization problem and verify whether the solution satisfies the constraints; Step S56: Output the optimal unit output scheme.

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