Hybrid pumped storage power station dispatching method, device, system and storage medium

Abstract

The application relates to a hybrid pumped storage power station scheduling method, device and system and a storage medium, and relates to the technical field of power system scheduling. The method at least solves the problem that the flexible adjustment capability of a hybrid pumped storage power station cannot be accurately quantified, so that the output states of various units in the power station cannot be accurately scheduled, and the peak-valley difference of residual load cannot be effectively reduced. The method comprises the following steps: constructing a scheduling model according to the residual load of each preset period in a target scheduling period and the overall flexible adjustment capability of the hybrid pumped storage power station; determining the first output range of each hydroelectric unit and the second output range of each pumped storage unit according to a first constraint and a second constraint; coupling the first output range and the second output range to solve the scheduling model and obtain the target operating power of the pumped storage unit; and scheduling the operating conditions of the various hydroelectric units and the various pumped storage units according to the target operating power.

Description

Technical Field

[0001] This application relates to the field of power system dispatching technology, and in particular to a method, apparatus, system and storage medium for dispatching hybrid pumped storage power stations. Background Technology

[0002] Developing renewable energy sources such as wind and solar power is a key measure to address the increasingly severe climate change and energy crisis. However, due to the strong intermittency and volatility of their output, large-scale grid connection of wind and solar power has seriously impacted the safe and efficient operation of the power grid. Utilizing the regulation capabilities of other flexible power sources can smooth out the fluctuations in wind and solar power output, thereby increasing their absorption ratio in the grid. Flexible regulation capability refers to the ability to quickly and flexibly adjust the increase or decrease of power generation output according to grid demand. The flexible regulation capability of cascade hydropower stations is mainly limited by reservoir capacity, water flow time lag, and other conditions, making it impossible to achieve a rapid and precise global optimal response. Pumped storage power stations (PS), as a typical flexible regulation power source, play an important role in the construction of new power systems. However, the available site resources for traditional pumped storage power stations are becoming increasingly depleted. In recent years, adding pumped storage units between two hydropower stations, i.e., building hybrid pumped storage hydropower stations (HPSHPP) on the basis of cascade hydropower stations (CHPs), has become an effective way to improve the system's flexible regulation capability. However, the current traditional regulation capability estimation method that relies solely on the upper and lower limits of the output of each unit in the hydropower station is difficult to accurately quantify the flexible regulation capability of hybrid pumped storage hydropower stations, and cannot effectively improve the smoothing of grid load fluctuations and reduce the peak-valley difference of the residual load of the power generation system. Summary of the Invention

[0003] This invention provides a method, apparatus, system, and storage medium for dispatching a hybrid pumped storage power station, aiming to at least solve the problem that the inability to accurately quantify the flexible regulation capacity of a hybrid pumped storage power station leads to the inability to accurately dispatch the output status of each unit within the power station, resulting in the inability to effectively reduce the peak-valley difference of the remaining load. The technical solution of this invention is as follows:

[0004] According to a first aspect of the present invention, a method for scheduling a hybrid pumped storage power station is provided, applied to a hybrid pumped storage power station; the hybrid pumped storage power station is a power station established by adding pumped storage units to a cascade hydropower station structure; the hybrid pumped storage power station includes multiple hydropower units and multiple pumped storage units; the method includes: constructing a scheduling model based on the remaining load of each preset time period within a target scheduling cycle and the overall flexible regulation capability of the hybrid pumped storage power station; the scheduling model aims to minimize the variance of the remaining load and maximize the flexible regulation capability within the target scheduling cycle; determining a first output range for each hydropower unit and a second output range for each pumped storage unit based on a first constraint and a second constraint; the first constraint characterizes the constraint conditions of the cascade hydropower station and the hydropower units; the second constraint characterizes the constraint conditions of the hybrid pumped storage power station and the pumped storage units; coupling the first output range and the second output range to solve the scheduling model to obtain the target operating power of the pumped storage units; the target operating power includes power generation and pumping power; and scheduling the operating conditions of each hydropower unit and each pumped storage unit according to the target operating power.

[0005] As an implementation method, the overall flexible regulation capacity includes both overall upward and downward flexible regulation capacity. Before constructing the scheduling model, based on the remaining load of each preset time period within the target scheduling cycle and the overall flexible regulation capacity of the hybrid pumped storage power station, the overall flexible regulation capacity of the hybrid pumped storage power station is quantified. Specifically, this involves: determining the first upward flexible regulation capacity of the hydropower units based on the upward regulation rate of the cascade hydropower stations and the maximum output of each hydropower unit; and determining the first downward flexible regulation capacity of the hydropower units based on the downward regulation rate of the cascade hydropower stations and the minimum output of each hydropower unit; and determining the first downward flexible regulation capacity of the hydropower units based on the upward regulation rate under the power generation condition and the pumping condition under the pumping condition. The second upward flexible regulation capacity of the pumped storage unit is determined based on the upward adjustment rate, minimum output under pumping conditions, and unit capacity; the second downward flexible regulation capacity of the pumped storage unit is determined based on the downward adjustment rate under power generation conditions, the downward adjustment rate under pumping conditions, minimum output under power generation conditions, and unit capacity of the hybrid pumped storage power station; the overall upward flexible regulation capacity is determined based on the first and second upward flexible regulation capacities; and the overall downward flexible regulation capacity is determined based on the first and second downward flexible regulation capacities.

[0006] In this embodiment, based on determining the upper and lower limits of the output of each hydropower unit and pumped storage unit, and combining the dynamic operating conditions of the hydropower units and pumped storage units, the flexible regulation capability of the hydropower units of the cascade hydropower station and the flexible regulation capability of the pumped storage units of the hybrid pumped storage power station are quantified by adjusting the rates of adjustment under both power generation and pumping conditions, thereby more accurately quantifying the overall flexible regulation capability of the hybrid pumped storage power station.

[0007] As one implementation method, a scheduling model is constructed based on the remaining load of each preset time period within the target scheduling cycle and the overall flexible regulation capacity of the hybrid pumped storage power station. This includes: determining a first objective function based on the sum of the overall upward and downward flexible regulation capacities for each preset time period; the first objective function is the maximum flexible regulation capacity; determining a second objective function based on the difference between the remaining load and its mean for each preset time period within the target scheduling cycle; the second objective function is the minimum remaining load variance; determining the priority of the first and second objective functions based on preset weighting coefficients; combining the first and second objective functions using a weighted combination method based on the priority to obtain a set of objective functions; and constructing a scheduling model based on the set of objective functions.

[0008] In this implementation, the scheduling model is a dual-objective model that minimizes the variance of the grid's remaining load and maximizes the system's flexible regulation capability. The load situation within the target scheduling period is determined by pre-set weighting coefficients, thus defining the preferred objective function. When minimizing the variance of the grid's remaining load is the primary objective, peak shaving and valley filling are prioritized for load fluctuations; when maximizing the system's flexible regulation capability is the primary objective, emergency power support for the grid is prioritized. In this way, the hybrid pumped storage power station can achieve a dynamic trade-off between flexible response capability and stable grid operation, adapting to the scheduling needs of different scenarios.

[0009] As one implementation method, the first constraints include: the first water balance constraint, the first reservoir capacity constraint, the net head constraint, the first power generation flow constraint, and the start-up and shutdown constraints of the hydropower unit.

[0010] Based on the first and second constraints, the first output range of each hydropower unit and the second output range of each pumped storage unit are determined, including: based on the first constraints of the cascade hydropower station and the hydropower unit, the nonlinear relationship between the net head and the first power generation flow rate is solved using the convex hull relaxation method to obtain the first output range of each hydropower unit.

[0011] In this implementation, the processing range of the hydropower unit is determined separately, and linearization methods such as McCormick convex hull relaxation are combined to effectively solve the complex nonlinear output-head-flow characteristics, ensuring the feasibility of application in actual engineering scenarios and improving the level of intelligent scheduling.

[0012] As one implementation method, the second constraint includes the second water balance constraint, the second power generation flow constraint, the pumping flow constraint, the net head constraint, and the pumped storage unit start-up and shutdown constraint; the second output range includes the second power generation output range and the second pumping output range.

[0013] Based on the first and second constraints, the first output range of each hydropower unit and the second output range of each pumped storage unit are determined, including: based on the second constraint, using the convex hull relaxation method to solve the nonlinear relationship between the net head and the second power generation flow rate under the power generation condition of the pumped storage unit, to obtain the second power generation output range of each pumped storage unit under the power generation condition; and solving the nonlinear relationship between the net head and the pumping flow rate under the pumping condition of the pumped storage unit, to obtain the second pumping output range of each pumped storage unit under the pumping condition.

[0014] In this embodiment, the pumped storage unit operates in two modes: power generation and pumping. The power generation output range and pumping output range of the pumped storage unit are determined separately to provide precise adjustment boundaries.

[0015] As one implementation method, the surplus load is the difference between the original load and the predicted output of photovoltaic and wind power and the operating power of pumped storage units.

[0016] The first and second output ranges are coupled together, and the scheduling model is solved to obtain the target operating power of the pumped storage unit. This includes: solving the scheduling model based on the first and second output ranges to obtain the target remaining load; and determining the target operating power of the pumped storage unit based on the target remaining load, the original load, and the predicted output of photovoltaic and wind power.

[0017] As one implementation method, the operating conditions of each hydropower unit and each pumped storage unit are scheduled according to the target operating power, including: determining the output value of each hydropower unit and each pumped storage unit according to the target operating power; scheduling the operating conditions of each hydropower unit as start-up or shutdown according to the output value; and scheduling the operating conditions of each pumped storage unit as discharge, pumping, or shutdown respectively.

[0018] In this implementation, the operating condition of the current load adjustment is determined as either power generation or consumption based on the power situation at the current time period. Based on the output value, the operating conditions of each hydropower unit and each pumped storage unit can be more accurately scheduled, thereby ensuring that the remaining load meets requirements. This effectively improves the smoothing of grid load fluctuations and reduces the peak-to-valley difference of the remaining load in the power generation system.

[0019] According to a second aspect of the present invention, a hybrid pumped storage power station dispatching device is provided, the device comprising:

[0020] The scheduling model construction unit is configured to construct a scheduling model based on the remaining load of each preset time period within the target scheduling cycle and the overall flexible regulation capability of the hybrid pumped storage power station; the scheduling model aims to minimize the variance of the remaining load and maximize the flexible regulation capability within the target scheduling cycle.

[0021] The solution unit is configured to determine the first output range of the hydropower unit and the second output range of the pumped storage unit based on the first and second constraints; couple the first and second output ranges to solve the scheduling model and obtain the target operating power of the pumped storage unit; the target operating power includes power generation and pumping power.

[0022] The scheduling unit is configured to schedule the operating conditions of each hydropower unit and each pumped storage unit according to the target operating power.

[0023] According to a third aspect of the present invention, a hybrid pumped storage power station is provided, comprising multiple hydroelectric generating units and multiple pumped storage units. The system is configured to perform a hybrid pumped storage power station scheduling method as described in the first aspect and any possible implementation thereof.

[0024] According to a fourth aspect of the present invention, a hybrid pumped storage power station scheduling device is provided, the device being configured to perform a hybrid pumped storage power station scheduling method as described in the first aspect and any possible implementation thereof.

[0025] According to a fifth aspect of the present invention, a computer-readable storage medium is provided, on which instructions are stored, such that when the instructions in the computer-readable storage medium are executed by a processor of a scheduling device, the scheduling device is able to perform a hybrid pumped storage power station scheduling method as described in the first aspect and any possible implementation thereof.

[0026] According to a sixth aspect of the present disclosure, a computer program product is provided, the computer program product including computer instructions, which, when executed on a scheduling device, cause the scheduling device to perform the hybrid pumped storage power station scheduling method of the first aspect and any possible implementation thereof.

[0027] The technical solutions provided by the embodiments of the present invention bring at least the following beneficial effects: Hybrid pumped storage power stations add pumped storage units with bidirectional regulation capabilities to the structure of cascade hydropower stations, changing the water flow between adjacent reservoirs from unidirectional to bidirectional, enhancing the regulation capability of the power system and utilizing water resources more effectively. By constructing a scheduling model aimed at minimizing the variance of the remaining load and maximizing the flexible regulation capability, a portion of flexible regulation capability can be reserved while ensuring the minimization of the variance of the remaining load and reducing the peak-valley difference of the remaining load. This better copes with sudden increases or decreases in grid power demand, improving the flexibility and stability of the entire hydropower system. Furthermore, by accurately determining the output range of each unit in the hybrid pumped storage hydropower station, the operating power of the pumped storage units can be determined more precisely, enabling more accurate scheduling of the operating conditions of each unit.

[0028] It should be understood that the above general description and the following detailed description are exemplary and explanatory only, and are not intended to limit this disclosure. Attached Figure Description

[0029] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this disclosure and, together with the description, serve to explain the principles of this disclosure, and are not intended to unduly limit this disclosure.

[0030] Figure 1 This is a schematic diagram of a hybrid pumped storage power station according to an exemplary embodiment;

[0031] Figure 2 This is a flowchart illustrating a hybrid pumped storage power station scheduling method according to an exemplary embodiment. Figure 1 ;

[0032] Figure 3 This is a flowchart illustrating a hybrid pumped storage power station scheduling method according to an exemplary embodiment. Figure 2 ;

[0033] Figure 4 This is a block diagram illustrating a hybrid pumped storage power station dispatching device according to an exemplary embodiment;

[0034] Figure 5 This is a schematic diagram of a hybrid pumped storage power station dispatching device according to an exemplary embodiment. Detailed Implementation

[0035] To enable those skilled in the art to better understand the technical solutions of this disclosure, the technical solutions in the embodiments of this disclosure will be clearly and completely described below with reference to the accompanying drawings.

[0036] It should be noted that the terms "first," "second," etc., used in the specification, claims, and accompanying drawings of this disclosure are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of this disclosure described herein can be implemented in orders other than those illustrated or described herein. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with this disclosure. Rather, they are merely examples of apparatuses and methods consistent with some aspects of this disclosure as detailed in the appended claims.

[0037] Before providing a detailed description of the hybrid pumped storage power station scheduling method provided in the embodiments of this application, let's first briefly introduce the application scenarios and implementation environment involved in the embodiments of this application.

[0038] First, a brief introduction to the application scenarios involved in this application will be given.

[0039] Developing renewable energy sources such as wind and solar power is a key measure to address the increasingly severe climate change and energy crisis. However, due to the strong intermittency and volatility of their output, large-scale grid connection of wind and solar power has seriously impacted the safe and efficient operation of the power grid. Utilizing the regulation capabilities of other flexible power sources can smooth out the fluctuations in wind and solar power output, thereby increasing their absorption ratio in the grid. Flexible regulation capability refers to the ability to quickly and flexibly adjust the increase or decrease of power generation output according to grid demand. The flexible regulation capability of cascade hydropower stations is mainly limited by reservoir capacity, water flow time lag, and other conditions, making it impossible to achieve a rapid and precise global optimal response. Pumped storage power stations (PS), as a typical flexible regulation power source, play an important role in the construction of new power systems. However, the available site resources for traditional pumped storage power stations are becoming increasingly depleted. In recent years, adding pumped storage units between two hydropower stations, i.e., building hybrid pumped storage hydropower stations (HPSHPP) on the basis of cascade hydropower stations (CHPs), has become an effective way to improve the system's flexible regulation capability. However, the current traditional regulation capability estimation method that relies solely on the upper and lower limits of the output of each unit in the hydropower station is difficult to accurately quantify the flexible regulation capability of hybrid pumped storage hydropower stations, and cannot effectively improve the smoothing of grid load fluctuations and reduce the peak-valley difference of the residual load of the power generation system.

[0040] To address the aforementioned issues, this application proposes a hybrid pumped storage power station scheduling method. The hybrid pumped storage power station adds pumped storage units with bidirectional regulation capabilities to the structure of a cascade hydropower station, transforming the water flow between adjacent reservoirs from unidirectional to bidirectional, thereby enhancing the power system's regulation capabilities and utilizing water resources more effectively. By constructing a scheduling model that aims to minimize the residual load variance and maximize flexible regulation capability, this method ensures that while minimizing the residual load variance and effectively reducing the peak-to-valley difference in residual load, it also reserves some flexible regulation capability to better cope with sudden increases or decreases in grid demand, improving the flexibility and stability of the entire hydropower system. Furthermore, by accurately determining the output range of each unit in the hybrid pumped storage hydropower station, the operating power of the pumped storage units can be more precisely determined, enabling more accurate scheduling of the operating conditions of each unit.

[0041] Secondly, the implementation architecture involved in this application will be briefly introduced below.

[0042] Figure 1 This is a schematic diagram of a hybrid pumped storage power station provided in this application. Figure 1As shown, this hybrid pumped storage power station is a hydropower station constructed by adding multiple pumped storage units 11 to a cascade hydropower station. The cascade hydropower station includes multiple hydroelectric generating units 12. Therefore, the hybrid pumped storage power station includes multiple pumped storage units 11 and multiple hydroelectric generating units 12.

[0043] The aforementioned pumped storage units 11 and multiple hydroelectric units 12 are connected via wired or wireless networks.

[0044] The multiple pumped storage units 11 are configured to determine the output value of each pumped storage unit according to the target operating power, and thereby schedule the operating conditions of each pumped storage unit as discharge mode, pumping mode or shutdown mode respectively.

[0045] The multiple hydropower units 12 are configured to determine the output value of each hydropower unit according to the target operating power, and thereby schedule the operating conditions of each hydropower unit to start-up or shutdown.

[0046] Figure 2 This is a flowchart illustrating a hybrid pumped storage power station scheduling method according to an exemplary embodiment. Figure 1 ,like Figure 2 As shown, the scheduling method for the hybrid pumped storage power station includes the following steps.

[0047] S21. Based on the remaining load of each preset time period within the target scheduling cycle and the overall flexible regulation capability of the hybrid pumped storage power station, a scheduling model is constructed.

[0048] The scheduling model aims to minimize the variance of the remaining load and maximize the flexibility of adjustment within the target scheduling period.

[0049] To fully leverage the superior regulation performance of hybrid pumped storage power stations and reduce the peak-to-valley difference in the system's residual load, thereby stabilizing it and reducing reliance on frequent adjustments from conventional power sources such as thermal power, the peak-shaving objective function is designed to minimize the variance of the residual load. Simultaneously, given the continuously increasing penetration rate of renewable energy sources, there is an urgent need to ensure the supply of power sources for flexible regulation of the system; therefore, an objective function to maximize flexible regulation capability is further constructed.

[0050] Furthermore, the set of objective functions is determined according to the following formulas (1) to (4), thereby constructing a scheduling model.

[0051] First, the minimum remaining load variance is determined based on the difference between the remaining load and its mean value in each preset time period within the target scheduling cycle, as shown in formulas (1) and (2) below.

[0052]

[0053] Where f1 is the first objective function for minimizing the variance of the remaining load; T is the total number of time periods in the scheduling cycle; Let be the remaining load of the power grid at time t.

[0054]

[0055] in, Let be the remaining load of the power grid at time t; The initial load of the power grid at time t; and These represent the predicted output of photovoltaic and wind power at time t, respectively. For the power of the pumped storage unit, when When the value is positive, the pumped-storage unit is in power generation mode. When the value is negative, the pumped storage unit is in pumping mode.

[0056] Secondly, the maximum flexible adjustment capacity is determined based on the sum of the overall upward and downward flexible adjustment capacities for each preset time period, as shown in the following formula (3).

[0057]

[0058] Where f2 is the second objective function that maximizes the flexible adjustment capability; T is the total number of time periods in the scheduling cycle; To improve the overall flexibility of regulation; The overall flexibility adjustment capability has been reduced.

[0059] Third, based on preset weighting coefficients, the priority of maximum flexible adjustment capacity and minimum residual load variance is determined.

[0060] Specifically, the objective function is a multi-objective optimization problem. Based on the electricity consumption during the target scheduling cycle, the priorities of the maximum flexible adjustment capacity and the minimum residual load variance are determined in advance.

[0061] Understandably, the scheduling model is a dual-objective model that minimizes the variance of the grid's remaining load and maximizes the system's flexible regulation capability. It determines the load situation within the target scheduling period through pre-set weighting coefficients, thus defining the preferred objective function. When minimizing the variance of the grid's remaining load is the primary objective, priority is given to peak shaving and valley filling for load fluctuations; when maximizing the system's flexible regulation capability is the primary objective, priority is given to ensuring emergency power support for the grid. In this way, hybrid pumped storage power stations can achieve a dynamic trade-off between flexible response capability and stable grid operation, adapting to the scheduling needs of different scenarios.

[0062] Fourth, based on priority, the maximum flexible adjustment capacity and the minimum residual load variance are combined using a weighted combination method to obtain the set of objective functions.

[0063] Considering the different dimensions of the first and second objective functions, a weighted combination method is used to solve the problem based on pre-set priorities and weight coefficients, resulting in a set of objective functions.

[0064] For example, the set of objective functions is determined according to formula (4).

[0065]

[0066] Where f1 is the first objective function to minimize the variance of the remaining load; and f2 is the second objective function to maximize the flexible adjustment capability. and ω1 represents the reference values ​​for the first objective function and the second objective function, respectively; ω1 is the weight coefficient.

[0067] In step S21 above, the overall flexible regulation capacity of the hybrid pumped storage power station is quantified to determine the overall upward and downward flexible regulation capacity.

[0068] Hybrid pumped storage hydroelectric power stations (HPSHP) supplement the pumping function by adding pumped storage units to cascade hydroelectric power stations (CHPs). Furthermore, the power generation capacity of the pumped storage units is equivalent to extending the output capacity of conventional hydroelectric power stations, thereby increasing the maximum output level of the power station. The flexible regulation capacity of a hybrid pumped storage hydroelectric power station, both upward and downward, is determined jointly by the conventional hydroelectric generating units and the pumped storage units.

[0069] First, the first flexible regulation capacity for upward regulation is determined based on the upward regulation rate of the cascade hydropower stations and the maximum output of each hydropower unit; and second, the first flexible regulation capacity for downward regulation is determined based on the downward regulation rate of the cascade hydropower stations and the minimum output of each hydropower unit.

[0070] In one implementation, the regulation rate of a conventional hydropower unit is typically 20% of its capacity per minute, with a response time of less than 20 seconds, indicating that the hydropower unit possesses a relatively fast regulation rate and response capability. However, in actual operation, the flexible regulation capability of a hydropower unit is affected by various factors. From the perspective of unit safety, rapid changes in flow rate within a short period can damage the turbine blades, thereby affecting the unit's lifespan. From the perspective of water resource allocation, if a hydropower station suddenly operates at full capacity or shuts down, it will cause drastic fluctuations in downstream water levels, potentially causing adverse effects on the ecological environment and navigation. Therefore, considering various factors, the actual regulation rate of a hydropower station is generally calculated as 20% of its rated capacity per 15 minutes.

[0071] For example, the flexible regulation capacity of the hydropower unit is determined according to formulas (5) and (6), including a first upward flexible regulation capacity and a first downward flexible regulation capacity.

[0072] Specifically, see formulas (5) and (6) below.

[0073]

[0074] in, and These represent the first upward and first downward flexible regulation capabilities of the cascade hydropower stations at time t, respectively; N h Number of hydroelectric power stations and These represent the upward and downward adjustment rates of the hydropower station, respectively; Δt is the duration of each scheduling period. and These are the maximum and minimum outputs of the j-th generating unit in hydropower station i, respectively.

[0075] Secondly, based on the upward adjustment rate under the power generation condition, the upward adjustment rate under the pumping condition, the minimum output under the pumping condition, and the unit capacity of the hybrid pumped storage power station, the second upward adjustment flexible regulation capacity is determined; and based on the downward adjustment rate under the power generation condition, the downward adjustment rate under the pumping condition, the minimum output under the power generation condition, and the unit capacity of the hybrid pumped storage power station, the second downward adjustment flexible regulation capacity is determined.

[0076] Hybrid pumped storage power stations have bidirectional regulation capabilities, taking into account both power generation and pumping conditions.

[0077] For example, the flexible regulation capacity of the hybrid pumped storage unit is determined according to formulas (7) and (8), including a second upward flexible regulation capacity and a second downward flexible regulation capacity.

[0078]

[0079] in, and These are the second upward and second downward flexible regulation capabilities of the hybrid pumped storage power station, respectively. and The pumped storage unit n is in the operating state under both power generation and pumping conditions; and These are the upward and downward adjustment rates of pumped storage unit n under power generation conditions, respectively. and These are the upward and downward adjustment rates under pumping conditions, respectively. This refers to the maximum output of pumped storage unit n, i.e., the unit capacity. and These represent the minimum output of pumped storage unit n under power generation and pumping conditions, respectively.

[0080] Finally, the overall upward flexible adjustment capability is determined based on the first and second upward flexible adjustment capabilities. And, the overall downward flexible adjustment capability is determined based on the first and second downward flexible adjustment capabilities.

[0081] For example, based on formulas (9) and (10), the overall flexible regulation capacity of the hybrid pumped storage power station is determined by combining the flexible regulation capacity of the cascade hydropower station and the overall flexible regulation capacity of the hybrid pumped storage power station.

[0082]

[0083] in, To improve the overall flexibility of regulation; To reduce the overall flexibility of regulation; The first adjustment is to enhance the flexibility of the adjustment capability; The first adjustment is to reduce the flexibility of the adjustment capability; This is to improve the flexibility of the second adjustment. This is the second adjustment to the flexible adjustment capability.

[0084] In this embodiment, based on determining the upper and lower limits of the output of each hydropower unit and pumped storage unit, and combining the dynamic operating conditions of the hydropower unit and pumped storage unit, the flexible regulation capability of the hydropower unit of the cascade hydropower station and the flexible regulation capability of the pumped storage unit of the mixed pumped storage power station are quantified by adjusting the up and down adjustment rates under the dual operating conditions of power generation and pumping, so as to more accurately quantify the overall flexible regulation capability of the mixed pumped storage power station.

[0085] S22, based on the first constraint and the second constraint, determine the first output range of each hydropower unit and the second output range of each pumped storage unit.

[0086] The first constraint characterizes the constraints on the cascade hydropower stations and hydropower units.

[0087] The second constraint characterizes the constraints on the hybrid pumped storage power station and the pumped storage unit.

[0088] In some implementations, such as Figure 3 As shown, step S22 is specifically implemented through the following steps S221 and S222.

[0089] S221, determine the first output range of each hydropower unit.

[0090] Based on the first constraints of the cascade hydropower stations and hydropower units, the nonlinear relationship between the net head and the first power generation flow rate is solved using the convex hull relaxation method, thereby obtaining the first output range of each hydropower unit.

[0091] The first constraints include the first water balance constraint, the first reservoir capacity constraint, the net head constraint, the first power generation flow constraint, and the start-up and shutdown constraints of the hydropower units.

[0092] For example, the first output range is determined according to formulas (11) to (27).

[0093] First, determine the first constraint according to formulas (11) to (23).

[0094] First, determine the first water balance constraint.

[0095] The first water balance constraint is determined based on the inflow and outflow of the reservoir.

[0096] For example, the first water balance constraint is determined according to formulas (11) and (12).

[0097]

[0098] Among them, v i,t Let I be the water storage capacity of the i-th reservoir at the end of time t; i,t Let be the inflow rate of water flowing into the i-th reservoir at time t; Let be the outflow from the i-th reservoir at time t; Δt is the time resolution of the scheduling, which is 0.25 hours; 3600 in the formula represents the number of seconds used for unit conversion, i.e., 3600 seconds.

[0099]

[0100] in, Let be the outflow rate of the i-th reservoir at time t; Let be the power generation flow of the j-th generating unit in the i-th hydropower station at time t; Let be the discharge flow of the i-th hydropower station at time t. Since water discharge mainly occurs during the flood season, when hydropower units are usually operating at full capacity, water discharge scheduling is not practically meaningful. Therefore, only the operation during the dry season and normal water season are considered.

[0101] It is understandable that, based on the structure of a cascade hydropower station, there are multiple hydropower stations within a cascade, each including a reservoir. These reservoirs are upstream and downstream of each other. Therefore, for a given reservoir of a hydropower station, there are both inflow and outflow flows simultaneously, and the water volume within the reservoir is a dynamically changing process. Considering the water balance constraints under the influence of natural water flow allows for a more accurate determination of the treatment range of the outflowing generating units.

[0102] Secondly, the capacity constraints of the first reservoir were determined.

[0103] The capacity constraints of the first reservoir are determined based on the maximum and minimum water storage capacity of the reservoir.

[0104] For example, the first reservoir capacity constraint is determined according to formulas (13) to (15).

[0105] The water storage capacity of the reservoir should meet the following upper and lower limit constraints, as shown in formula (13).

[0106]

[0107] Among them, v i,t Let be the water storage capacity of the i-th reservoir at the end of time t. V i and These are the minimum and maximum water storage capacities of the i-th reservoir, respectively.

[0108] The initial water storage capacity and the final water storage capacity of the reservoir are shown in the following formulas (14) and (15), respectively.

[0109]

[0110] This represents the initial water storage volume. This represents the final water storage volume; ρ i This is an adjustment coefficient for the final water storage, allowing the final water storage to fluctuate within a certain range, thereby improving the flexibility of scheduling.

[0111] Third, determine the first power generation flow constraint.

[0112] The first power generation flow constraint is determined based on the upper and lower limits of the power generation flow of each hydropower unit in the hydropower station.

[0113] For example, the first power generation flow constraint is determined according to formula (16).

[0114]

[0115] in, Let be the power generation flow of the j-th generating unit in the i-th hydropower station at time t; and These represent the lower and upper limits of the power generation flow of the j-th generating unit in hydropower station i, respectively.

[0116] Fourth, determine the head constraint for clean water.

[0117] The inlet and outlet water levels of the dam are determined based on the reservoir's storage capacity and outflow. The net head is determined based on the difference between the inlet and outlet water levels. Thus, the net head constraint is determined based on the minimum and maximum net head.

[0118] For example, the net head constraint is determined according to formulas (17) to (21).

[0119] Under normal operating conditions, the water level in front of the dam can be expressed as a function of the reservoir's storage capacity, while the tailrace level can be expressed as a function of the outflow. The water levels in front of the dam and the tailrace level are shown in the following formulas (17) and (18).

[0120]

[0121] Among them, z i,t and These are the water levels in front of the dam and the tailrace, respectively; v i,t Let be the water storage capacity of the i-th reservoir at the end of time t; and These are the relationship functions between water level and reservoir storage, and the relationship function between tailwater level and outflow. These two types of functional relationships can be fitted using the least squares method.

[0122] In one implementation, the above formula (17) is fitted to a first-order function based on the measured data, as shown in formula (19).

[0123]

[0124] Among them, z i,t The water level in front of the dam; v i,t Let be the water storage capacity of the i-th reservoir at the end of time t.

[0125] The net head can be represented by the difference between the water level in front of the dam and the tailwater level, as shown in the following formula (20).

[0126]

[0127] in, Let z be the net head of the i-th hydropower station at time t; i,t and These are the water levels in front of the dam and the tailwater level, respectively.

[0128] The head of the purified water should meet the upper and lower limit constraints, as shown in the following formula (21).

[0129]

[0130] in, Let be the net head of the i-th hydropower station at time t; H i and These are the minimum and maximum net water head of the i-th reservoir, respectively.

[0131] Fifth, determine the start-up and shutdown constraints of the hydropower units.

[0132] Based on the start-up and shutdown decision variables of each hydropower unit in the hydropower station, the start-up and shutdown constraints of the hydropower units are determined.

[0133] For example, the start-up and shutdown constraints of the hydropower unit are determined according to formulas (22) and (23).

[0134]

[0135] in, and These are the decision variables for starting and stopping the j-th generating unit in hydropower station i; Let be the operating state of the j-th generating unit in hydropower station i, which is a 0-1 variable.

[0136] Understandably, one or more hydropower units in a hydropower station can be started and generated according to power generation requirements.

[0137] Secondly, the first output range is determined based on the correlation between water head and power generation flow.

[0138] For example, the first output range is determined according to formulas (24) to (27).

[0139] Hydropower output is a nonlinear function of water head and power generation flow, as shown in formula (24). In practical engineering applications, hydropower output is usually approximated as being directly proportional to the product of water head and power generation flow, as shown in formula (25).

[0140]

[0141] in, This refers to the output value of the hydroelectric generator unit; Let be the power generation flow of the j-th generating unit in the i-th hydropower station at time t; For clean water head; It is a non-linear functional relationship; This is the overall output coefficient.

[0142] The above formula (25) is linearized by using the McCormick convex hull relaxation method to linearize the product term, thereby transforming formula (25) into a set of inequality constraints, as shown in the following formula (26).

[0143]

[0144] in, This refers to the output value of the hydroelectric generator unit; This is the overall output coefficient; and These are the lower and upper limits of the power generation flow of the j-th generating unit in hydropower station i, respectively; Let be the net head of the i-th hydropower station at time t; H i and These are the minimum and maximum net head of the i-th reservoir, respectively; Let be the power generation flow of the j-th generating unit in the i-th hydropower station at time t.

[0145] The first output range of hydropower should meet the upper and lower limit constraints, as shown in the following formula (27).

[0146]

[0147] in, and These are the maximum and minimum outputs of the j-th generating unit in hydropower station i, respectively. Let be the operating state of the j-th generating unit in hydropower station i, which is a 0-1 variable.

[0148] In this implementation, by combining linearization techniques such as McCormick convex hull relaxation, the complex nonlinear output-head-flow characteristics can be effectively solved, ensuring the feasibility of application in actual engineering scenarios and improving the level of intelligent scheduling.

[0149] S222, determine the second output range for each pumped storage unit.

[0150] Based on the second constraint, the nonlinear relationship between the net head and the second power generation flow rate under the power generation condition of the pumped storage unit is solved using the convex hull relaxation method, thereby obtaining the second power generation output range under the power generation condition of each pumped storage unit; and the nonlinear relationship between the net head and the pumping flow rate under the pumping condition of the pumped storage unit is solved, thereby obtaining the second pumping output range under the pumping condition of each pumped storage unit.

[0151] The second output range includes the second power generation output range and the second pumping output range.

[0152] The second set of constraints includes the second water balance constraint, the second power generation flow constraint, the pumping flow constraint, the net head constraint, and the pumped storage unit start-up and shutdown constraint.

[0153] For example, the second output range is determined according to formulas (28) to (41).

[0154] First, determine the second constraint according to formulas (28) to (37).

[0155] First, determine the second water balance constraint.

[0156] The reservoir's storage capacity is determined based on the inflow and outflow rates; and the second water balance constraint is determined by considering the power generation and pumping flow rates of the pumped storage units.

[0157] For example, the second water balance constraint is determined according to formulas (28) and (29).

[0158] Compared to traditional cascade hydropower stations, the water balance constraints of hybrid pumped storage hydropower stations require additional consideration of the power generation flow and pumping flow of the pumped storage units.

[0159]

[0160] Among them, v i,t Let I be the water storage capacity of the i-th reservoir at the end of time t; i,t Let be the inflow rate of water flowing into the i-th reservoir at time t; Let be the outflow from the i-th reservoir at time t; Δt is the time resolution of the scheduling, which is 0.25 hours; 3600 in the formula represents the number of seconds used for unit conversion, i.e., 3600 seconds.

[0161]

[0162] in, This refers to the net flow rate of the pumped storage unit. The flow rate of a pumped storage unit under pumping conditions; The flow rate of pumped storage unit n under power generation conditions.

[0163] Secondly, the constraints on the second power generation flow rate and the pumping flow rate are determined.

[0164] The second power generation flow constraint is determined based on the minimum and maximum power generation flow under the power generation condition; the pumping flow constraint is determined based on the minimum and maximum pumping flow under the pumping condition.

[0165] For example, the second power generation flow constraint and the pumping flow constraint are determined according to formulas (30) and (31).

[0166]

[0167] in, and These are the minimum and maximum power generation flows of the nth pumped storage unit under power generation conditions, respectively. and These are its minimum and maximum pumping flow rates under pumping conditions, respectively.

[0168] Third, determine the head constraint for clean water.

[0169] The head constraint is determined based on the minimum and maximum head. As shown in formula (21) above, it will not be repeated here.

[0170] Fourth, determine the start-up and shutdown constraints for pumped storage units.

[0171] Based on the 0-1 state variables of the pumped storage unit under power generation and pumping conditions, the start-up and shutdown constraints of the pumped storage unit are determined.

[0172] For example, the start-up and shutdown constraints of pumped storage units are determined according to formulas (32) to (37).

[0173]

[0174] in, and These are the 0-1 state variables of the nth pumped storage unit under power generation and pumping conditions, respectively. This indicates that the same pumped storage unit cannot perform power generation and pumping operations simultaneously.

[0175]

[0176] in, and These are the start-up and shutdown decision variables for the nth pumped storage unit under power generation conditions; and These are the start-up and shutdown decision variables under pumping conditions; and These are the 0-1 state variables of the nth pumped storage unit under power generation and pumping conditions, respectively. This indicates that different pumped storage units can only be in one of the following operating conditions: pumping or power generation, or a shutdown state.

[0177] Secondly, based on the correlation between water head and power generation flow, the output range of the pumped storage unit under both power generation and pumping conditions is determined, thereby determining the second output range.

[0178] For example, the second output range is determined according to formulas (38) to (41).

[0179] As known from formula (24) in step S221, the output can be approximated as being proportional to the product of the head and the power generation flow. The output expressions of the pumped storage unit under the two operating conditions of power generation and pumping are shown in formulas (38) and (39) below.

[0180]

[0181] in, To generate electricity for pumped storage units; For pumping power output of pumped storage units; The flow rate of pumped storage unit n under power generation conditions; The flow rate of the pumped storage unit under pumping conditions; This is the power generation output coefficient; This is the pumping capacity coefficient; For water purification.

[0182] Since both equations (38) and (39) contain nonlinear terms, they need to be linearized. The linearization process is the same as that of equation (26) in step S221, and will not be repeated here.

[0183] The upper and lower limits of the power generation and pumping output of the pumped storage unit are shown in the following formulas (40) and (41).

[0184]

[0185] in, and These are the 0-1 state variables of the nth pumped storage unit under power generation and pumping conditions, respectively. and These are the lower and upper limits of its power generation capacity, respectively. and These represent the lower and upper limits of its pumping power, respectively.

[0186] S23, the first output range and the second output range are coupled, and the scheduling model is solved to obtain the target operating power of the pumped storage unit.

[0187] The target operating power includes power generation and pumping power.

[0188] Specifically, the scheduling model is solved based on the first and second output ranges to obtain the target remaining load; the target operating power of the pumped storage unit is determined based on the target remaining load, the original load, and the predicted output of photovoltaic and wind power.

[0189] According to formula (2) in step S21 above, the remaining load is the difference between the original load and the predicted output of photovoltaic and wind power and the operating power of pumped storage units.

[0190] In one implementation, the load curve of the original load of the power grid and the predicted output of photovoltaic and wind power are input into the dispatch model to obtain the target remaining load, thereby determining the target operating power of the pumped storage unit required to reach the target remaining load.

[0191] S24, based on the target operating power, schedules the operating conditions of each hydropower unit and each pumped storage unit.

[0192] Specifically, based on the target operating power, the output value of each hydropower unit and each pumped storage unit is determined; based on the output value, the operating conditions of each hydropower unit are respectively scheduled as start-up or shutdown, and the operating conditions of each pumped storage unit are respectively scheduled as discharge, pumping, or shutdown.

[0193] Understandably, in terms of electricity, pumped storage units can convert excess electrical energy in the system into the potential energy of water. Through the coordinated operation of hydroelectric units and pumped storage units, the potential energy of water can be converted back into electrical energy, achieving a two-way conversion between electrical and potential energy. Therefore, when renewable energy output is large and the system cannot fully absorb it, hybrid pumped storage hydropower stations can play a pumping role, converting excess electrical energy into the potential energy of water for storage. When load demand is high and the system's power supply faces pressure, hybrid pumped storage hydropower stations can meet the system's supply and demand balance through power generation.

[0194] Therefore, based on whether the target operating power is power generation or pumping power, it is determined whether the hybrid pumped storage power station is in power generation or pumping mode at this time, and the operating mode of each hydropower unit and each pumped storage unit is scheduled accordingly.

[0195] In one implementation, when the hybrid pumped-storage power station is determined to be in power generation mode, multiple hydroelectric generators and multiple pumped-storage units are scheduled to release water and generate electricity. The number of operating units is determined based on the target operating power; if the target operating power is low, fewer units are started and generating electricity, and vice versa. When the hybrid pumped-storage power station is determined to be in pumping mode, multiple hydroelectric generators are scheduled to be shut down and not generate electricity, while multiple pumped-storage units are scheduled to be in pumping mode, converting electrical energy into potential energy for storage.

[0196] To achieve the above functions, the hybrid pumped storage power station dispatching device includes the corresponding hardware structure and / or software modules for performing each function. Those skilled in the art will readily recognize that, based on the algorithmic steps of the examples described in conjunction with the embodiments disclosed herein, this application can be implemented in hardware or a combination of hardware and computer software. Whether a function is executed in hardware or by computer software driving hardware depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of this application.

[0197] This disclosure also provides an embodiment such as Figure 4 The hybrid pumped storage power station dispatching device shown includes: a dispatching model construction unit 401, a solution unit 402, and a dispatching unit 403.

[0198] The scheduling model construction unit 401 is configured to construct a scheduling model based on the remaining load of each preset time period within the target scheduling cycle and the overall flexible regulation capability of the hybrid pumped storage power station; the scheduling model aims to minimize the variance of the remaining load and maximize the flexible regulation capability within the target scheduling cycle.

[0199] The solver unit 402 is configured to determine the first output range of the hydropower unit and the second output range of the pumped storage unit based on the first and second constraints; couple the first and second output ranges to solve the scheduling model and obtain the target operating power of the pumped storage unit; the target operating power includes power generation and pumping power.

[0200] The scheduling unit 403 is configured to schedule the operating conditions of each hydropower unit and each pumped storage unit according to the target operating power.

[0201] As a means of implementation, overall flexible adjustment capability includes both overall upward and downward flexible adjustment capability.

[0202] The scheduling model construction unit 401 is specifically configured to, before constructing the scheduling model, quantify the overall flexible regulation capacity of the mixed pumped storage power station based on the remaining load of each preset time period within the target scheduling cycle and the overall flexible regulation capacity of the mixed pumped storage power station. The specific methods include: determining the first upward flexible regulation capacity of the hydropower units based on the upward regulation rate of the cascade hydropower stations and the maximum output of each hydropower unit; and determining the first downward flexible regulation capacity of the hydropower units based on the downward regulation rate of the cascade hydropower stations and the minimum output of each hydropower unit; and determining the first downward flexible regulation capacity of the hydropower units based on the upward regulation rate of the cascade hydropower stations and the minimum output of each hydropower unit; and determining the upward flexible regulation capacity of the mixed pumped storage power station based on the power generation conditions under the specified conditions. The second upward flexible regulation capacity of the pumped storage unit is determined based on the regulation rate, the upward regulation rate under pumping conditions, the minimum output under pumping conditions, and the unit capacity. The second downward flexible regulation capacity of the pumped storage unit is also determined based on the downward regulation rate under power generation conditions, the downward regulation rate under pumping conditions, the minimum output under power generation conditions, and the unit capacity. The overall upward flexible regulation capacity is determined based on the first and second upward flexible regulation capacities. Finally, the overall downward flexible regulation capacity is determined based on the first and second downward flexible regulation capacities.

[0203] As one implementation method, the scheduling model construction unit 401 is specifically configured as follows: A first objective function is determined based on the sum of the overall upward and downward flexible adjustment capabilities for each preset time period; the first objective function is the maximum flexible adjustment capability. A second objective function is determined based on the difference between the remaining load and its mean value for each preset time period within the target scheduling cycle; the second objective function is the minimum remaining load variance. The priority of the first and second objective functions is determined based on preset weighting coefficients. Based on the priority, the first and second objective functions are combined using a weighted combination method to obtain a set of objective functions. A scheduling model is constructed based on the set of objective functions.

[0204] As one implementation method, the first constraints include: the first water balance constraint, the first reservoir capacity constraint, the net head constraint, the first power generation flow constraint, and the start-up and shutdown constraints of the hydropower unit.

[0205] The solution unit 402 is specifically configured to determine the first output range of each hydropower unit and the second output range of each pumped storage unit based on the first and second constraints. This includes: using the convex hull relaxation method to solve the nonlinear relationship between the net head and the first power generation flow rate based on the first constraints of the cascade hydropower station and the hydropower unit, thereby obtaining the first output range of each hydropower unit.

[0206] As one implementation method, the second constraint includes the second water balance constraint, the second power generation flow constraint, the pumping flow constraint, the net head constraint, and the pumped storage unit start-up and shutdown constraint; the second output range includes the second power generation output range and the second pumping output range.

[0207] The solution unit 402 is specifically configured to determine the first output range of each hydropower unit and the second output range of each pumped storage unit based on the first and second constraints. This includes: solving the nonlinear relationship between the net head and the second power generation flow rate under the power generation condition of the pumped storage unit using the convex hull relaxation method based on the second constraint, thereby obtaining the second power generation output range of each pumped storage unit under the power generation condition; and solving the nonlinear relationship between the net head and the pumping flow rate under the pumping condition of the pumped storage unit, thereby obtaining the second pumping output range of each pumped storage unit under the pumping condition.

[0208] As one implementation method, the surplus load is the difference between the original load and the predicted output of photovoltaic and wind power and the operating power of pumped storage units.

[0209] The solution unit 402 is specifically configured to couple the first output range and the second output range to solve the scheduling model and obtain the target operating power of the pumped storage unit. This includes: solving the scheduling model based on the first output range and the second output range to obtain the target remaining load; and determining the target operating power of the pumped storage unit based on the target remaining load, the original load, and the predicted output of photovoltaic and wind power.

[0210] As one implementation method, the scheduling unit 403 is specifically configured to schedule the operating conditions of each hydropower unit and each pumped storage unit according to the target operating power, including: determining the output value of each hydropower unit and each pumped storage unit according to the target operating power; scheduling the operating conditions of each hydropower unit to start-up or shutdown state according to the output value, and scheduling the operating conditions of each pumped storage unit to discharge state, pumping state, or shutdown state respectively.

[0211] Regarding the apparatus in the above embodiments, the specific manner in which each unit module performs its operations has been described in detail in the embodiments related to the method, and will not be elaborated upon here.

[0212] Figure 5 This is a schematic diagram of a hybrid pumped storage power station dispatching device provided in this application. Figure 5 The hybrid pumped storage power station dispatching device 50 may include at least one processor 501 and a memory 503 for storing processor-executable instructions. The processor 501 is configured to execute the instructions in the memory 503 to implement the hybrid pumped storage power station dispatching method in the following embodiments.

[0213] In addition, the hybrid pumped storage power station dispatching equipment 50 may also include a communication bus 502, at least one communication interface 504, an input device 506, and an output device 505.

[0214] The processor 501 may be a processor (central processing unit, CPU), a microprocessor unit, an ASIC, or one or more integrated circuits for controlling the execution of the program of the present application.

[0215] The communication bus 502 may include a path for transmitting information between the aforementioned components.

[0216] Communication interface 504 uses any transceiver-like device for communicating with other devices or communication networks, such as Ethernet, radio access network (RAN), wireless local area networks (WLAN), etc.

[0217] Input device 506 is used to receive input signals and output device 505 is used to output signals.

[0218] Memory 503 may be a read-only memory (ROM) or other type of static storage device capable of storing static information and instructions, random access memory (RAM) or other type of dynamic storage device capable of storing information and instructions, or electrically erasable programmable read-only memory (EEPROM), compact disc read-only memory (CD-ROM) or other optical disc storage, optical disc storage (including compressed optical discs, laser discs, optical discs, digital versatile optical discs, Blu-ray discs, etc.), magnetic disk storage media or other magnetic storage devices, or any other medium capable of carrying or storing desired program code in the form of instructions or data structures and accessible by a computer, but not limited thereto. Memory may exist independently and be connected to the processing unit via a bus. Memory may also be integrated with the processing unit.

[0219] The memory 503 stores instructions for executing the scheme of this application, and the processor 501 controls the execution. The processor 501 executes the instructions stored in the memory 503 to implement the functions of the method of this application.

[0220] In a specific implementation, as one example, the processor 501 may include one or more CPUs, for example... Figure 5 CPU0 and CPU1 in the CPU.

[0221] In a specific implementation, as one example, the hybrid pumped storage power station dispatching equipment 50 may include multiple processors, such as... Figure 5 Processors 501 and 507 are shown in the diagram. Each of these processors can be a single-core (single-CPU) processor or a multi-core (multi-CPU) processor. A processor here can refer to one or more devices, circuits, and / or processing cores used to process data (such as computer program instructions).

[0222] The dispatching equipment of the hybrid pumped storage power station, such as Figure 5 The diagram includes a processor 501 and a memory 503 for storing executable instructions of the processor 501. The processor 501 is configured to execute the executable instructions to implement the hybrid pumped storage power station scheduling method as described in any of the possible embodiments above. Since the same technical effects can be achieved, further details are omitted here to avoid repetition.

[0223] This application also provides a computer-readable storage medium. When the instructions in the computer-readable storage medium are executed by the processor of a hybrid pumped storage power station scheduling device or a hybrid pumped storage power station scheduling equipment, the hybrid pumped storage power station scheduling device or the hybrid pumped storage power station scheduling equipment can execute the hybrid pumped storage power station scheduling method as described in any of the above possible embodiments. And it can achieve the same technical effect; to avoid repetition, it will not be described again here.

[0224] This application also provides a computer program product, including a computer program or instructions, which are executed by a processor as a hybrid pumped storage power station scheduling method according to any of the possible implementations described above. It achieves the same technical effects, and to avoid repetition, will not be described again here.

[0225] Other embodiments of this application will readily occur to those skilled in the art upon consideration of the specification and practice of the invention disclosed herein. This application is intended to cover any variations, uses, or adaptations of this application that follow the general principles of this application and include common knowledge or customary techniques in the art not disclosed herein. The specification and examples are to be considered exemplary only, and the true scope and spirit of this application are indicated by the following claims.

[0226] It should be understood that this application is not limited to the precise structure described above and shown in the accompanying drawings, and various modifications and changes can be made without departing from its scope. The scope of this application is limited only by the appended claims.

Claims

1. A method for dispatching a hybrid pumped storage power station, characterized in that, The method is applied to a hybrid pumped storage power station; the hybrid pumped storage power station is a power station built by adding pumped storage units to a cascade hydropower station structure; the hybrid pumped storage power station includes multiple hydropower units and multiple pumped storage units; the method includes: A scheduling model is constructed based on the remaining load of each preset time period within the target scheduling cycle and the overall flexible regulation capability of the hybrid pumped storage power station; the scheduling model aims to minimize the variance of the remaining load and maximize the flexible regulation capability within the target scheduling cycle. Based on the first constraint and the second constraint, a first output range for each of the hydropower units and a second output range for each of the pumped storage units are determined; the first constraint characterizes the constraint conditions of the cascade hydropower station and the hydropower units; the second constraint characterizes the constraint conditions of the hybrid pumped storage power station and the pumped storage units. The first output range and the second output range are coupled together, and the scheduling model is solved to obtain the target operating power of the pumped storage unit; the target operating power includes power generation and pumping power. Based on the target operating power, the operating conditions of each of the hydroelectric generator units and each of the pumped storage units are scheduled.

2. The method for dispatching a hybrid pumped storage power station according to claim 1, characterized in that, The overall flexible adjustment capability includes the overall upward flexible adjustment capability and the overall downward flexible adjustment capability; Before constructing the scheduling model based on the remaining load of each preset time period within the target scheduling cycle and the overall flexible regulation capacity of the hybrid pumped storage power station, the method quantifies the overall flexible regulation capacity of the hybrid pumped storage power station, specifically including: The first upward flexible regulation capacity of the hydropower units is determined based on the upward regulation rate of the cascade hydropower stations and the maximum output of each hydropower unit; and the first downward flexible regulation capacity of the hydropower units is determined based on the downward regulation rate of the cascade hydropower stations and the minimum output of each hydropower unit. Based on the up-regulation rate under power generation conditions, the up-regulation rate under pumping conditions, the minimum output under pumping conditions, and the unit capacity of the hybrid pumped storage power station, the second up-regulation flexible regulation capacity of the pumped storage unit is determined; and based on the down-regulation rate under power generation conditions, the down-regulation rate under pumping conditions, the minimum output under power generation conditions, and the unit capacity of the hybrid pumped storage power station, the second down-regulation flexible regulation capacity of the pumped storage unit is determined. The overall upward flexible adjustment capability is determined based on the first upward flexible adjustment capability and the second upward flexible adjustment capability; and the overall downward flexible adjustment capability is determined based on the first downward flexible adjustment capability and the second downward flexible adjustment capability.

3. The method for dispatching a hybrid pumped storage power station according to claim 2, characterized in that, The scheduling model is constructed based on the remaining load of each preset time period within the target scheduling cycle and the overall flexible regulation capability of the hybrid pumped storage power station, including: A first objective function is determined based on the sum of the overall upward and downward flexible adjustment capabilities for each preset time period; the first objective function is used to determine the maximum flexible adjustment capability. A second objective function is determined based on the difference between the remaining load and its mean value for each preset time period within the target scheduling cycle. The second objective function is used to determine the minimum remaining load variance. The priorities of the first objective function and the second objective function are determined according to preset weighting coefficients; Based on the aforementioned priorities, the first objective function and the second objective function are combined using a weighted combination method to obtain a set of objective functions; The scheduling model is constructed based on the set of objective functions.

4. The method for dispatching a hybrid pumped storage power station according to claim 1, characterized in that, The first constraints include: first water balance constraint, first reservoir capacity constraint, net head constraint, first power generation flow constraint, and hydropower unit start-up and shutdown constraint; The step of determining the first output range of each hydropower unit and the second output range of each pumped storage unit based on the first and second constraints includes: Based on the first constraints of the cascade hydropower stations and the hydropower units, the nonlinear relationship between the net head and the first power generation flow rate is solved using the convex hull relaxation method to obtain the first output range of each hydropower unit.

5. The method for dispatching a hybrid pumped storage power station according to claim 4, characterized in that, The second constraint includes a second water balance constraint, a second power generation flow constraint, a pumping flow constraint, the net head constraint, and a pumped storage unit start-up and shutdown constraint; the second output range includes a second power generation output range and a second pumping output range. The step of determining the first output range of each hydropower unit and the second output range of each pumped storage unit based on the first and second constraints includes: Based on the second constraint, the nonlinear relationship between the net head and the second power generation flow rate under the power generation condition of the pumped storage unit is solved using the convex hull relaxation method to obtain the second power generation output range under the power generation condition of each pumped storage unit; and the nonlinear relationship between the net head and the pumping flow rate under the pumping condition of the pumped storage unit is solved to obtain the second pumping output range under the pumping condition of each pumped storage unit.

6. The method for dispatching a hybrid pumped storage power station according to claim 5, characterized in that, The remaining load is the difference between the original load and the predicted output of photovoltaic and wind power and the operating power of pumped storage units; The step of coupling the first output range and the second output range, solving the scheduling model, and obtaining the target operating power of the pumped-storage unit includes: The scheduling model is solved based on the first output range and the second output range to obtain the target remaining load; The target operating power of the pumped storage unit is determined based on the target remaining load, the original load, and the predicted output of photovoltaic and wind power.

7. The method for dispatching a hybrid pumped storage power station according to claim 6, characterized in that, The step of scheduling the operating conditions of each of the hydropower units and each of the pumped storage units according to the target operating power includes: Based on the target operating power, determine the output value of each hydropower unit and each pumped storage unit; Based on the output value, the operating conditions of each of the hydropower units are respectively scheduled as start-up or shutdown, and the operating conditions of each of the pumped storage units are respectively scheduled as discharge, pumping, or shutdown.

8. A hybrid pumped storage power station dispatching device, characterized in that, The device includes: The scheduling model construction unit is configured to construct a scheduling model based on the remaining load of each preset time period within the target scheduling cycle and the overall flexible regulation capability of the hybrid pumped storage power station; the scheduling model aims to minimize the variance of the remaining load and maximize the flexible regulation capability within the target scheduling cycle. The solving unit is configured to determine the first output range of the hydropower unit and the second output range of the pumped storage unit based on the first and second constraints; couple the first output range and the second output range to solve the scheduling model to obtain the target operating power of the pumped storage unit; the target operating power includes power generation and pumping power; The scheduling unit is configured to schedule the operating conditions of each of the hydropower units and each of the pumped storage units according to the target operating power.

9. A hybrid pumped storage power station, characterized in that, The hybrid pumped storage power station includes multiple hydroelectric generator units and multiple pumped storage units; It is configured to perform the hybrid pumped storage power station scheduling method as described in any one of claims 1-7.

10. A computer-readable storage medium storing instructions thereon, characterized in that, When the instructions in the computer-readable storage medium are executed by the processor of the hybrid pumped storage power station scheduling device, the hybrid pumped storage power station scheduling device is able to perform the hybrid pumped storage power station scheduling method as described in any one of claims 1-7.

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