Method, system and equipment for determining day-ahead operation mode of pumped storage power station in double-high power grid and medium

Abstract

The invention is suitable for the technical field of economic dispatching of a power system, and discloses a method, a system, equipment and a medium for determining a day-ahead operation mode of a pumped storage power station in a double-high power grid, and the method comprises the steps: obtaining load prediction data and technical parameters of each unit; performing unit combinatorial optimization through technical parameters of each unit, and constructing a day-ahead economic dispatching model by combining multiple constraint conditions and taking minimization of system operation cost as a target function; the day-ahead economic dispatching model is solved through the load prediction data, and the power and the standby state of the pumped storage unit are obtained; and according to the peak clipping and valley filling characteristics, the day-ahead operation mode of each time period is determined through the power and the standby state of the pumped storage unit. According to the method, the technical advantages of all the units are coordinated through the peak clipping and valley filling characteristics of the pumped storage units, accurate determination of the day-ahead operation mode of the pumped storage power station and the optimal scheduling strategy of coordination and cooperation of all types of units are achieved, and the operation economical efficiency of the double-high power system is remarkably improved.

Description

Technical Field

[0001] This invention relates to the field of economic dispatch technology for power systems, and in particular to a method, system, equipment, and medium for determining the day-ahead operation mode of a pumped storage power station in a high-voltage power grid. Background Technology

[0002] Currently, the world is promoting energy structure transformation, and the development of new energy technologies is also progressing rapidly. The "dual-high" power system, namely a high proportion of renewable energy and a high proportion of power electronic equipment, has become the main development direction of the power system. However, in the dual-high system, renewable energy power generation such as wind power and photovoltaic power generation has obvious characteristics, namely, unstable output and inability to accurately predict in advance. Therefore, once the output of renewable energy power generation fluctuates, the power system needs to rely on other adjustable units for peak shaving and frequency regulation in order to maintain supply and demand balance and stabilize system operation.

[0003] In power system operation, centralized energy storage systems demonstrate outstanding peak-shaving and frequency regulation capabilities, playing a crucial role in improving power supply-demand matching, optimizing system operational stability, and enhancing energy conversion efficiency. Especially in high-voltage and high-efficiency power systems, the peak-shaving function of pumped storage power stations is becoming increasingly critical. Based on these characteristics of such systems, a systematic exploration of the operating principles and control methods of centralized energy storage in peak-shaving and frequency regulation ancillary services is needed, particularly regarding how pumped storage can participate in day-ahead economic dispatch.

[0004] Day-ahead economic dispatch refers to the process of formulating generation plans 24 hours before electricity market transactions. With the large-scale integration of renewable energy into the grid, its optimization objectives are twofold: first, to minimize the amount of renewable energy wasted during the dispatch cycle; and second, to reduce the total system operating cost. From the dispatch process perspective, it mainly includes three key steps: first, a preliminary dispatch plan is formulated based on day-ahead market transactions; then, combined with real-time updated forecast information, the previous plan is dynamically revised using intraday rolling optimization, which effectively smooths out fluctuations in renewable energy output while adapting to real-time changes in load demand; finally, real-time dispatch, responding quickly to the actual system operating status and market signals to ensure the safe and stable operation of the power grid.

[0005] Therefore, developing a centralized energy storage day-ahead economic dispatch method suitable for high-voltage power systems and giving full play to the peak-shaving and valley-filling role of pumped storage is of great significance for improving the overall operating efficiency of the power system. Summary of the Invention

[0006] In view of the aforementioned problems with existing peak-shaving functions, this invention is proposed.

[0007] Therefore, this invention provides a method, system, equipment, and medium for determining the day-ahead operation mode of pumped storage power stations in a dual-high-voltage power grid to address the problems of poor system operation economy caused by high proportion of renewable energy grid connection; difficulty in absorbing high proportion of renewable energy and serious wind and solar curtailment; difficulty in coordinating multiple complex units and insufficient adaptability of dispatching models; and insufficient potential tapping and extensive operation mode of pumped storage power stations.

[0008] To solve the above-mentioned technical problems, the present invention provides the following technical solution: In a first aspect, the present invention provides a method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid, comprising: Obtain load forecast data and technical parameters of each generating unit; By optimizing the combination of units based on their technical parameters and considering multiple constraints, a day-ahead economic dispatch model is constructed with the objective function of minimizing system operating costs. The day-ahead economic dispatch model is solved by using load forecast data to obtain the power and standby status of pumped storage units; Based on peak shaving and valley filling characteristics, the daytime operation mode for each period is determined by the power and standby status of the pumped storage units.

[0009] As a preferred embodiment of the method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in this invention, the balance constraints include: The balance constraint is that the total load of the system is equal to the sum of the total output of each unit, where the total output of pumped storage is the power determined by the operating state of the pumped storage unit: when the output of the pumped storage unit is positive, the pumped storage unit is in turbine mode; when the output of the pumped storage unit is negative, the pumped storage unit is in pump mode.

[0010] As a preferred embodiment of the method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in this invention, wherein minimizing the system operating cost is an objective function, including: System operating costs include: wind curtailment costs, solar curtailment costs, hydropower curtailment costs, nuclear power curtailment costs, and the power generation and start-up costs of each unit; By pre-setting the calculation period and combining the system operating cost and the operating status of each unit, the objective function is obtained.

[0011] As a preferred embodiment of the method for determining the day-ahead operation mode of pumped storage power stations in a dual-high-voltage power grid as described in this invention, the day-ahead economic dispatch model is solved using the Gurobi Optimizer based on load forecast data to obtain the charging and discharging power and standby status of the pumped storage units.

[0012] As a preferred embodiment of the method for determining the day-ahead operation mode of a pumped storage power station in a high-voltage power grid as described in this invention, the day-ahead operation mode for each time period is determined based on the peak-shaving and valley-filling characteristics, using the power and standby status of the pumped storage units, including: Based on load forecast data, we can identify periods of low, high, and stable load. By combining the charging power during off-peak hours, the pumped storage unit is determined to enter the pumping mode to absorb excess electrical energy. By combining peak load periods with discharge power, it is determined whether the pumped storage unit enters turbine operation mode to release stored energy and participate in power generation; By combining periods of stable load with standby status, it is determined that the pumped storage unit is in standby mode and does not charge or discharge.

[0013] As a preferred embodiment of the method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in this invention, the multiple constraints include: Based on various technical parameters, multiple constraints are determined, including: balance constraints, spinning reserve constraints, start-up and shutdown time constraints, unit ramp-up and load reduction constraints, pumped storage unit constraints, hydropower unit constraints, nuclear power unit constraints, and the operating output constraints of thermal power, hydropower, wind power, photovoltaic power, and nuclear power.

[0014] As a preferred embodiment of the method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in this invention, the method includes: acquiring load forecast data and technical parameters of each unit, including: Load forecast data is obtained through the power grid dispatch center, including: the load forecast value for the next day, reserve demand, and the forecast output of wind power and photovoltaic power. Technical parameters of each generating unit are obtained through power grid operation records, which include thermal power generation, hydropower generation, wind power generation, photovoltaic power generation, nuclear power generation, and pumped storage units.

[0015] Secondly, the present invention provides a system for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid, comprising: The acquisition module is used to acquire load forecast data and technical parameters of each generating unit; The model building module is used to optimize the combination of units by using the technical parameters of each unit, and to construct a day-ahead economic dispatch model by taking multiple constraints and minimizing the system operating cost as the objective function. The solver module is used to solve the day-ahead economic dispatch model using load forecast data to obtain the power and standby status of pumped storage units; The execution module is used to determine the daytime operation mode for each period based on the peak shaving and valley filling characteristics, and the power and standby status of the pumped storage units.

[0016] Thirdly, the present invention provides an electronic device, comprising: Memory and processor; The memory is used to store computer-executable instructions, and the processor is used to execute the computer-executable instructions. When the computer-executable instructions are executed by the processor, the steps of the method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid are implemented.

[0017] Fourthly, the present invention provides a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, implement the steps of the method for determining the day-ahead operating mode of a pumped storage power station in the dual-high-voltage power grid.

[0018] Compared with existing technologies, the beneficial effects of this invention are as follows: By applying the peak-shaving and valley-filling characteristics of pumped storage units to the day-ahead economic dispatch of high-voltage power systems, this invention establishes an optimization model that minimizes operating costs, achieving precise determination of the day-ahead operation mode of pumped storage power stations and optimal dispatch strategies for the coordinated operation of various types of units. This method can fully leverage the peak-shaving and frequency-regulating characteristics of pumped storage units, coordinate the technical advantages of thermal power units, hydropower units, wind power units, photovoltaic units, nuclear power units, and pumped storage units, and significantly improve the operational economy of high-voltage power systems. Attached Figure Description

[0019] To more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings used in the following description of the embodiments will be briefly introduced. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0020] Figure 1 This is a schematic diagram of the overall process for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid according to an embodiment of the present invention.

[0021] Figure 2 This is a schematic diagram of the unit output during each time period in the method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid according to an embodiment of the present invention.

[0022] Figure 3 This is a schematic diagram of the unit output during each time period in the method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid according to an embodiment of the present invention.

[0023] Figure 4 This is a schematic diagram comparing the total operating costs under different operating modes of the method for determining the day-ahead operating mode of a pumped storage power station in a high-voltage power grid according to an embodiment of the present invention. Detailed Implementation

[0024] To make the above-mentioned objects, features, and advantages of the present invention more apparent and understandable, specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments of the present invention, and not all of them. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the protection scope of the present invention.

[0025] Example 1, referring to Figure 1 As an embodiment of the present invention, a method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid is provided, comprising: S100: Obtain load forecast data and technical parameters of each unit; S200: Optimize unit combination by using the technical parameters of each unit, and construct a day-ahead economic dispatch model by combining multiple constraints and minimizing system operating costs as the objective function. S300: Solve the day-ahead economic dispatch model using load forecast data to obtain the power and standby status of pumped storage units; S400: Based on peak shaving and valley filling characteristics, the daytime operation mode for each period is determined by the power and standby status of the pumped storage unit.

[0026] It should be noted that the high-energy-density power grid is a complex power system with a high proportion of renewable energy and a high proportion of power electronic equipment. During its operation, parameters such as load demand, renewable energy output, and grid power flow fluctuate dramatically, causing rapid changes in the system's power balance and node voltage. Affected by disturbances such as extreme weather and equipment failures, the system's operating state can deviate significantly from the normal range, making online assessment of fault propagation paths and system resilience levels difficult, and risk warning and control decisions often lag behind. At the same time, due to the deep coupling and interaction between multiple energy subsystems, local faults can easily trigger chain reactions, thereby endangering the power supply security of the entire system. Therefore, optimizing the day-ahead operation mode and coordinating dispatch of pumped storage power stations in the high-energy-density power grid is crucial.

[0027] Therefore, to address the aforementioned issues of optimizing and coordinating the day-ahead operation mode, the day-ahead economic dispatch model is constructed through steps S100-S400. Based on the acquired load forecast data and the technical parameters of each unit, and combined with various types of constraints, the parameters of each unit are optimized by combining the units. The objective function is to minimize the system operating cost, thereby constructing a day-ahead economic dispatch model. Furthermore, based on the peak-shaving and valley-filling characteristics of pumped storage units, the system switches to turbine operation mode for power generation during peak load periods and switches to pump operation mode for energy storage during off-peak load periods.

[0028] Example 2, refer to Figure 1 As an embodiment of the present invention, based on the above embodiment, a method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid is provided.

[0029] In this embodiment of the application, obtaining load forecast data and technical parameters of each unit in step S100 includes the following steps A1-A2: A1: Load forecast data is obtained through the power grid dispatch center, including: the load forecast value for the next day, reserve demand, and the forecast output of wind power and photovoltaic power. A2: Obtain the technical parameters of each unit through the power grid operation file, which includes thermal power generation, hydropower generation, wind power generation, photovoltaic power generation, nuclear power generation and pumped storage units.

[0030] Specifically, the technical parameters include the maximum power, minimum power, power generation cost coefficient, start-up cost, uphill rate, downhill rate, minimum operating time, minimum downtime, and cold start time of the thermal power unit. Maximum pumping power, maximum power generation, energy storage capacity, turbine efficiency, pump efficiency, and upper and lower reservoir water level limits of pumped storage units; Maximum power, minimum power, reservoir capacity constraints, flow constraints, and water balance constraints of hydropower units; Rated power, adjustable power range, power regulation rate, minimum operating time and low power operating time limit, and load factor of nuclear power units; Rated power of wind turbine generator set; Rated power of photovoltaic units; The technical parameters of various generating units are derived from the power grid operation records, including the rated power, efficiency, and constraint parameters of each unit.

[0031] In an optional implementation, the acquisition of load forecast data and technical parameters of each unit in step S100 can also be achieved through a multi-timescale data fusion mechanism. For example, the load forecast data and the new energy power output forecast are rolling update data, including day-ahead forecasts, intraday ultra-short-term forecasts, and real-time monitoring data. The technical parameters of each unit include static rated parameters and dynamic operating parameters, wherein the dynamic operating parameters are acquired in real time through the unit status monitoring system, including current available capacity, equipment health status, and real-time efficiency curves.

[0032] In another optional implementation, the acquisition of load forecast data and technical parameters of each unit in step S100 can also be used for credibility assessment and data repair. For example, credibility assessment is based on historical forecast error distribution and real-time data mutation detection, and data repair uses interpolation algorithms or time series forecasting models based on physical law constraints to repair missing or unreliable data.

[0033] In this embodiment of the application, step S200 optimizes the unit combination by using the technical parameters of each unit, and constructs a day-ahead economic dispatch model by combining multiple constraints and minimizing the system operating cost as the objective function, including the following steps B1-B2: B1: Construct a function with the objective of minimizing system operating costs; Specifically, the objective function of the current economic dispatch model is: In the formula, This represents the total number of generating units. For the calculation period; For system operating costs; For time period index, ; For unit indexing, ; For thermal power units exist The running status at any given moment; For thermal power units exist The running status at any given moment; For thermal power units The cost of generating electricity at time t; Indicates thermal power unit The startup cost; Cost of wind curtailment; Cost of abandoning light; Cost of water disposal; Costs associated with abandoning nuclear power.

[0034] in, For thermal power units exist The running state at any given time can be represented as: The cost of generating electricity from thermal power units is determined as follows: in, , , For thermal power units Cost coefficient; For thermal power units exist Contributing to the cause at all times.

[0035] The start-up cost of thermal power units is determined as follows: in, For thermal power units Hot start cost; For thermal power units Cold start costs; For thermal power units Minimum downtime; For thermal power units up to the current moment The machine has been down for an extended period of time. For thermal power units Cold start time.

[0036] In an alternative implementation, step S200, which uses minimizing system operating costs as the objective function, can also include equipment lifespan loss costs, so that the optimization result is not only economically optimal, but also extends the lifespan of key equipment and reduces the total lifespan cost.

[0037] In another optional implementation, step S200 can also establish a multi-objective function with minimizing system operating cost as the objective function, using "minimizing total cost", "maximizing new energy consumption" and "minimizing carbon emissions" as the core optimization multi-objective functions.

[0038] B2: Constructing multiple constraints; ①Balance constraints: In the formula express Total load of the time-based system; , , , , , These include thermal power, photovoltaic power, hydropower, wind power, nuclear power, and pumped storage. Contributing effort at all times; when At this time, the pumped storage unit is in turbine mode. ;when At this time, the pumped storage unit is in pump mode. , For pumped storage units in The power generation capacity at any given moment, i.e. the power output of the turbine under operating conditions.

[0039] It should be noted that, in order to ensure that the power generation of the power system is fully matched with the load demand in each period, it is necessary to ensure that the power generation of the system is strictly balanced with the total load, so as to avoid power shortages or surpluses and thus achieve the safe and stable operation of the power system.

[0040] ② Rotational spare constraint: In the formula, For thermal power units At any moment Maximum power output; Indicates photovoltaic unit At any moment Power output; For hydroelectric generator units At any moment Maximum power output; Indicates wind turbine At any moment Maximum power output; Indicates nuclear power unit At any moment Maximum power output.

[0041] It should be noted that the spinning reserve constraint is to ensure the reliability of the power system when facing load fluctuations or faults. It is necessary to ensure that the system has sufficient reserve capacity so that it can be quickly put into use in case of emergencies, and to avoid system imbalance caused by a sudden increase in load demand.

[0042] ③ Output constraints for thermal power, hydropower, wind power, photovoltaic power, and nuclear power units: Operating output constraints of thermal power units: In the formula, For thermal power units exist Minimum active power output during a given time period For thermal power units exist Maximum active power output during a given time period.

[0043] Hydropower unit operating output constraints: In the formula, The operating state of hydropower unit s at time t; Let be the minimum output of hydropower unit s at time t; Let be the output of the hydropower unit s at time t; Let be the maximum output of the hydropower unit s at time t.

[0044] Wind turbine operating output constraints: In the formula, For wind turbines Minimum output at time t; For wind turbines The output at time t; For wind turbines Maximum output at time t.

[0045] Photovoltaic unit operating output constraints: In the formula, For photoelectric generator Minimum output at time t; For photoelectric generator The output at time t; For photoelectric generator Maximum output at time t.

[0046] Nuclear power unit operating output constraints: In the formula, For nuclear power units Minimum output at time t; For nuclear power units The output at time t; For nuclear power units Maximum output at time t.

[0047] It should be noted that, in order to ensure that the power output of each generating unit meets the safe operation standards at each time period, the output of each unit must be limited to its maximum and minimum power range to prevent overload operation or inefficient operation.

[0048] ④ Start-stop time constraints: To ensure the stability of the generator set during the adjustment of its operating status, sufficient transition time must be reserved to effectively avoid potential negative impacts on the normal operation of the unit. The specific limitations of this transition time are as follows: In the formula, This represents the time period during which any given unit has been running continuously up to time t. This represents the minimum operating time for any given unit.

[0049] ⑤ Unit ramp-up and load reduction constraints: To ensure a smooth and safe power regulation process for each unit, the rate of increase and decrease in power during regulation must be limited to avoid drastic fluctuations in power output within a short period. The specific limitations on this regulation rate are as follows: In the formula, Indicates the unit The uphill rate; Indicates the unit The downhill rate.

[0050] ⑥ Constraints of pumped storage units: To ensure the efficient and safe energy storage and release process of pumped-storage hydroelectric units, it is essential to effectively limit the unit's power generation and energy storage capacity to prevent damage caused by overcharging or over-discharging. The specific constraints are as follows: Hydropower generation constraints under turbine operating conditions: Pump status power constraints: In the formula, during the operation of a pumped storage power station, the maximum pumping power under pump conditions is determined by... express; This represents the energy storage level of the upper reservoir within a specific time period; system efficiency varies significantly under different operating modes, among which... This represents the energy conversion efficiency in pump mode. This reflects the efficiency performance of the water turbine when it is generating electricity.

[0051] ⑦ Hydropower unit constraints: To ensure the efficient operation of hydropower units during scheduling, their output must be reasonably limited. Considering the controllability of reservoir water volume and flow, it is crucial to avoid exceeding reservoir capacity or allowing water flow fluctuations to negatively impact power generation. This constraint ensures that the power output of hydropower units is reasonable throughout the various time periods and meets the requirements of water resource management and power generation capacity. The specific constraints on hydropower units are as follows: Water consumption balance constraints for fixed-head hydropower plants: In the formula, the flow rate of the hydropower plant is determined by the variable This indicates that the total available water resources of the power plant are determined by variables. express.

[0052] During the operation of a variable head hydropower plant, the water balance constraint can be expressed as: In the formula, hydropower plant exist The power generation flow and water abandonment flow for each time period are expressed as follows: and And the reservoir exist The natural inflow and storage capacity during the period are respectively determined by and Characterization.

[0053] The water balance constraints for a cascade hydropower system are: In the formula, Characterizing reservoirs To the reservoir When the water flow is stagnant, Indicates hydroelectric power station The collection of upstream associated reservoirs, and This represents the complete set of the entire cascade hydropower station group.

[0054] Variable head and power balance constraints of cascade hydropower plants: In the formula, the reservoir storage capacity parameter It can be represented as Shike Reservoir The water storage state quantity, and the water consumption coefficient This represents the hydroelectric plant Water consumption per unit of power generation under variable head or cascade operation conditions.

[0055] During the variable head operation of a cascade hydropower station reservoir, the initial and final states of the reservoir's water storage must meet specific constraints: In the formula, Reservoir The initial water storage capacity, The two key parameters, representing the final water storage volume, are both preset to fixed values ​​by the system.

[0056] ⑧ Nuclear power unit constraints: To ensure the safety and stability of nuclear power units, their power regulation range must be strictly controlled. The power regulation rate of nuclear power units is limited to ensure they operate within a specified safe range while consistently providing base load to the power system. This constraint prevents excessive fluctuations in nuclear power unit performance during dispatching, ensuring the stability and safety of system operation. The specific constraints on nuclear power units are as follows: Depth of regulation constraints: Power regulation rate constraint: Low-power operating time constraints: In the formula, For nuclear power unit control depth; Rated power of the nuclear power unit; This refers to the power regulation amount; For power adjustment time; For low-power operation time; This is a constraint factor.

[0057] In an optional implementation, the constraints on the pumped storage unit in step S200 can also include other constraints, such as a constraint on the number of operating condition switching: to limit the maximum number of pumping or power generation state switching in a day to prevent excessive wear of the equipment; or a constraint on the minimum continuous operating time: once the pumping or power generation mode is started, it must run continuously for at least a fixed period of time to meet the physical characteristics of the equipment.

[0058] In another optional implementation, the model constraints in step S200 can also be adjusted by introducing network power flow and node voltage safety constraints, taking into account the grid topology and grid security. For example, by introducing constraints based on DC power flow or linearized AC power flow, the safety of the scheduling scheme in the network structure can be ensured, preventing line overload and voltage exceedance.

[0059] In this embodiment of the application, step S300 involves solving the day-ahead economic dispatch model using load forecast data to obtain the charging and discharging power and standby status of the pumped storage unit, including: Specifically, based on load forecast data, the model aims to minimize system operating costs and solve for the optimal power output plan of the system within the scheduling cycle.

[0060] Because this problem involves both continuous and integer variables, and is large in scale with complex constraints, it is difficult to obtain the global optimum in a reasonable time using ordinary linear programming methods. Therefore, the advanced optimization solver GurobiOptimizer was selected as the computational tool. Gurobi has efficient branch-and-bound algorithms and cutting plane strategies, enabling it to quickly solve large-scale mixed-integer quadratic programming (MIQP) problems with a single objective, while guaranteeing the global optimum of the results.

[0061] In this embodiment of the application, step S400 determines the daytime operation mode for each time period based on the peak shaving and valley filling characteristics, using the power and standby status of the pumped storage unit, including: Specifically, pumped storage units have typical peak shaving and valley filling characteristics, that is, they use surplus electricity to pump water for energy storage during periods of low grid load and release the stored energy to generate electricity during periods of high grid load.

[0062] Furthermore, considering the grid load variation characteristics over 96 calculation periods and the peak-shaving and valley-filling characteristics of pumped storage units, the specific details are as follows: During periods of low load, there may be excess electricity in the system, at which time the pumped storage units will enter a charging state. Based on the calculation results of the charging power, it is determined that the units should absorb the excess electrical energy in pump mode, converting it into stored reservoir energy to await subsequent discharge demand.

[0063] During peak load periods, when electricity demand increases and a power grid shortage occurs, pumped storage units will enter turbine operation mode based on the discharge power calculation results, releasing stored energy to participate in power generation and supplement the power supply of the grid.

[0064] During periods of stable load or low charging and discharging demand, the standby status indicates that the pumped storage unit will be in a standby state, neither charging nor discharging, and will only operate at low power in pump mode during certain periods to maintain system power balance.

[0065] It should be noted that the specific operating pattern of pumped storage units is as follows: Pumped storage units mainly operate in turbine mode during peak electricity demand periods, such as the afternoon and evening after 12:00 PM, to participate in power generation and peak shaving; during off-peak periods, such as 2:00 AM to 8:00 AM, they enter pump mode to store energy; and between 8:00 AM and 12:00 PM, the system load is generally stable, and the units are mostly in shutdown or standby status, with short-term pumping operation only when necessary. This operating mode fully demonstrates the peak-shaving and valley-filling characteristics of pumped storage units, enabling them to supplement the power system load demand during peak load periods and absorb surplus power from the grid during off-peak periods. This makes the output curves of thermal power and hydropower units more stable, while ensuring the priority consumption of clean energy sources such as wind power, photovoltaic power, and nuclear power, thus improving the system's operational economy and stability.

[0066] Example 3, referring to Figures 2-4 As an embodiment of the present invention, based on the above embodiment, a simulation experiment is provided to determine the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid, so as to verify its feasibility and effectiveness.

[0067] The Guangxi regional power grid was selected as the simulation example. This region contains various types of generating units, including thermal power units, hydropower units, wind power units, photovoltaic units, nuclear power units, and pumped storage units.

[0068] Table 1 Information on various types of generating units in the simulation area

[0069] Table 1 provides information on various types of generating units participating in day-ahead economic dispatch.

[0070] Table 2 Classification of Power System Operation Modes

[0071] Table 2 shows two operating modes based on whether or not pumped storage units are considered.

[0072] The day-ahead economic dispatch model uses 15-minute intervals for data collection, dividing the day into 96 time periods. Based on the above data, the day-ahead economic dispatch model is solved, and Table 3 shows the resulting pumped storage unit regulation.

[0073] Table 3. Regulation Status of Pumped Storage Units

[0074] According to the statistical results in Table 3, the pumped storage power station completed 41 charging processes, 37 discharging processes, and 18 standby state transitions during the study period, with a total regulated power of 4319.845 MWh, which fully demonstrates the excellent performance of the system in peak and valley power load regulation.

[0075] Table 4 Comparison of total operating costs under different operating modes

[0076] Table 4 provides a comparison of the economics of the two operating modes.

[0077] It should be noted that, based on the decomposition results, the method for determining the day-ahead operation mode of pumped storage power stations in a dual-high-voltage power grid provided in this application is adopted. When the load forecast data and unit technical parameters are determined, the algorithm can quickly determine the operation mode of the pumped storage units in each time period. The pumped storage units mainly switch to pump operation during the midday and evening power receiving periods before 12:00 noon, and to turbine operation during the nighttime low-peak period from 2:00 to 8:00 pm. They are in standby mode during the midday period from 8:00 to 12:00 noon. According to the statistical results in Table 4, in terms of economic benefit assessment, after introducing pumped storage units, the total daily power generation cost of the system decreased from 6,373,807.32 yuan to 6,361,229.64 yuan, achieving a cost saving of 12,577.68 yuan. From the perspective of cost reduction, the cost reduction of the pumped storage unit in this case is relatively limited. This is mainly because the installed capacity of the pumped storage unit in this system is only 300MW, which is significantly smaller than other units in the system, thus limiting its peak-shaving performance to some extent. It should be noted that the core function of pumped storage technology is to achieve peak shaving and valley filling of loads. Specifically, it switches to turbine operation for power generation during peak load periods and switches to pump operation for energy storage during off-peak periods. This operating characteristic determines the extent of its overall economic benefits, but the research data still effectively verifies the positive economic role of pumped storage units.

[0078] Based on the analysis of the solution results Figure 2 and Figure 3The output distribution of the units in operating modes one and two at different times is shown respectively. Figure 4 The total operating costs under the two operating modes were compared and analyzed.

[0079] The research results show that by applying the day-ahead operation optimization method for pumped storage power stations in the dual-high-load power grid proposed in this paper, a mode of operation was achieved where thermal power units bear the base load and hydropower significantly increases its output during peak load periods on typical operating days, effectively leveraging the peak-shaving function of hydropower. In terms of power dispatch, clean energy sources such as nuclear power, wind power, and photovoltaic power are all fully absorbed, strictly adhering to the principle of priority dispatch in the power system. Comparative analysis reveals that the introduction of pumped storage units significantly improves system operating characteristics: absorbing excess power during off-peak periods and releasing stored power during peak periods, not only achieving the dispatch goal of prioritizing new energy consumption but also optimizing the overall system operating efficiency through a "peak shaving and valley filling" mechanism. Overall operational results show that this method achieves the goals of minimizing wind and solar curtailment and minimizing operating costs, demonstrating significant improvements in economic efficiency, new energy consumption capacity, and system peak-shaving capacity compared to traditional dispatch methods that do not consider pumped storage.

[0080] In summary, this invention fully leverages the peak-shaving function of pumped storage units by introducing them. Based on their valley-shaving and peak-filling characteristics, and combined with multiple types of constraints, a day-ahead economic dispatch model is constructed with minimizing system operating costs as the objective function, achieving the goal of minimizing operating costs. By obtaining charging power, discharging power, and reserve status, the operating mode of the pumped storage units in each time period is further determined, realizing the accurate determination of the day-ahead operating mode of the pumped storage power station and the optimal dispatch strategy for the coordinated operation of various types of units. By fully utilizing the peak-shaving and frequency-regulating characteristics of pumped storage units and coordinating the technical advantages of thermal power units, hydropower units, wind power units, photovoltaic units, nuclear power units, and pumped storage units, the operational economy of the high-voltage power system is significantly improved.

[0081] Example 4 illustrates a schematic scheme for determining the day-ahead operation mode of a pumped-storage power station in a high-voltage power grid. It should be noted that the technical solution of this system for determining the day-ahead operation mode of a pumped-storage power station in a high-voltage power grid is based on the same concept as the aforementioned method for determining the day-ahead operation mode of a pumped-storage power station in a high-voltage power grid. Details not described in detail in the technical solution of the system for determining the day-ahead operation mode of a pumped-storage power station in a high-voltage power grid in this example can be found in the description of the aforementioned method for determining the day-ahead operation mode of a pumped-storage power station in a high-voltage power grid.

[0082] This embodiment also provides a system for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid, including: The acquisition module is used to acquire load forecast data and technical parameters of each generating unit; The model building module is used to optimize the combination of units by using the technical parameters of each unit, and to construct a day-ahead economic dispatch model by taking multiple constraints and minimizing the system operating cost as the objective function. The solver module is used to solve the day-ahead economic dispatch model using load forecast data to obtain the power and standby status of pumped storage units; The execution module is used to determine the daytime operation mode for each period based on the peak shaving and valley filling characteristics, and the power and standby status of the pumped storage units.

[0083] This embodiment also provides an electronic device applicable to determining the day-ahead operating mode of a pumped storage power station in a dual-high-voltage power grid, comprising: a memory and a processor; the memory is used to store computer-executable instructions, and the processor is used to execute the computer-executable instructions to implement the method for determining the day-ahead operating mode of a pumped storage power station in a dual-high-voltage power grid as proposed in the above embodiment.

[0084] This embodiment also provides a storage medium storing a computer program that, when executed by a processor, implements the method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as proposed in the above embodiments.

[0085] The storage medium proposed in this embodiment and the method for determining the day-ahead operation mode of pumped storage power stations in the above embodiments belong to the same inventive concept. Technical details not described in detail in this embodiment can be found in the above embodiments, and this embodiment has the same beneficial effects as the above embodiments.

[0086] Based on the above description of the implementation methods, those skilled in the art can clearly understand that the present invention can be implemented using software and necessary general-purpose hardware, and of course, it can also be implemented using hardware. Based on this understanding, the technical solution of the present invention, or the part that contributes to the prior art, can be embodied in the form of a software product. This computer software product can be stored in a computer-readable storage medium, such as a computer floppy disk, read-only memory (ROM), random access memory (RAM), flash memory, hard disk, or optical disk, etc., including several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute the methods of the various embodiments of the present invention.

[0087] It should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and not to limit it. Although the present invention has been described in detail with reference to preferred embodiments, those skilled in the art should understand that modifications or equivalent substitutions can be made to the technical solutions of the present invention without departing from the spirit and scope of the technical solutions of the present invention, and all such modifications or substitutions should be covered within the scope of the claims of the present invention.

Claims

1. A method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid, characterized in that, include: Obtain load forecast data and technical parameters of each generating unit; By optimizing the combination of units based on their technical parameters and considering multiple constraints, a day-ahead economic dispatch model is constructed with the objective function of minimizing system operating costs. The day-ahead economic dispatch model is solved by using load forecast data to obtain the charging and discharging power and standby status of pumped storage units; Based on peak shaving and valley filling characteristics, the daytime operation mode for each period is determined by the power and standby status of the pumped storage units.

2. The method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in claim 1, characterized in that, The balance constraints include: The balance constraint is that the total load of the system is equal to the sum of the total output of each unit, where the total output of pumped storage is the power determined by the operating state of the pumped storage unit: when the output of the pumped storage unit is positive, the pumped storage unit is in turbine mode; when the output of the pumped storage unit is negative, the pumped storage unit is in pump mode.

3. The method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in claim 2, characterized in that, The objective function for minimizing the system operating cost includes: System operating costs include: wind curtailment costs, solar curtailment costs, hydropower curtailment costs, nuclear power curtailment costs, and the power generation and start-up costs of each unit; By pre-setting the calculation period and combining the system operating cost and the operating status of each unit, the objective function is obtained.

4. The method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in claim 3, further characterized by: Based on load forecast data, the day-ahead economic dispatch model is solved using the Gurobi Optimizer to obtain the charging and discharging power and standby status of the pumped storage units.

5. The method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in claim 4, characterized in that, Based on peak shaving and valley filling characteristics, the daytime operation mode for each period is determined by the power and standby status of the pumped storage units, including: Based on load forecast data, we can identify periods of low, high, and stable load. By combining the charging power during off-peak hours, the pumped storage unit is determined to enter the pumping mode to absorb excess electrical energy. By combining peak load periods with discharge power, it is determined whether the pumped storage unit enters turbine operation mode to release stored energy and participate in power generation; By combining periods of stable load with standby status, it is determined that the pumped storage unit is in standby mode and does not charge or discharge.

6. The method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in claim 5, characterized in that, The multiple constraints include: Based on various technical parameters, multiple constraints are determined, including: balance constraints, spinning reserve constraints, start-up and shutdown time constraints, unit ramp-up and load reduction constraints, pumped storage unit constraints, hydropower unit constraints, nuclear power unit constraints, and the operating output constraints of thermal power, hydropower, wind power, photovoltaic power, and nuclear power.

7. The method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in claim 6, characterized in that, Obtain load forecast data and technical parameters of each generating unit, including: Load forecast data is obtained through the power grid dispatch center; Technical parameters of each generating unit are obtained through power grid operation records, which include thermal power generation, hydropower generation, wind power generation, photovoltaic power generation, nuclear power generation, and pumped storage units.

8. A system for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid, comprising the method described in any one of claims 1-7, characterized in that, include: The acquisition module is used to acquire load forecast data and technical parameters of each generating unit; The model building module is used to optimize the combination of units by using the technical parameters of each unit, and to construct a day-ahead economic dispatch model by taking multiple constraints and minimizing the system operating cost as the objective function. The solver module is used to solve the day-ahead economic dispatch model using load forecast data to obtain the power and standby status of pumped storage units; The execution module is used to determine the daytime operation mode for each period based on the peak shaving and valley filling characteristics, and the power and standby status of the pumped storage units.

9. An electronic device, characterized in that, include: Memory and processor; The memory is used to store computer-executable instructions, and the processor is used to execute the computer-executable instructions. When the computer-executable instructions are executed by the processor, they implement the steps of the method for determining the day-ahead operation mode of a pumped storage power station in a dual-high-voltage power grid as described in any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that, It includes the steps of storing computer-executable instructions that, when executed by a processor, implement the method for determining the day-ahead operating mode of a pumped storage power station in a dual-high-voltage power grid as described in any one of claims 1 to 7.

Images