Pumped storage output optimization method and device based on whole plant modeling and medium

Abstract

The invention discloses a pumped storage output optimization method and device based on whole plant modeling and a medium, and the method comprises the steps: building a safety constraint unit combination through the combination and output of control units; establishing a security constraint economic dispatching model by controlling the stable state of the pumped storage power plant in various operation states; establishing a node electricity price model according to the supply-demand balance demand of each node in the electricity market; and simultaneously solving the combination and each model to obtain a unit output set of the pumped storage power plant, and adjusting the pumped storage power plant. According to the pumped storage output optimization method and device based on whole plant modeling and the medium, the unit output set of the pumped storage power plant is obtained by simultaneously solving the combination and the models of the pumped storage power plant, so that the pumped storage power plant can be effectively adjusted, and the output efficiency of the pumped storage power plant is improved. The problem that it is difficult to carry out coordinated scheduling on multiple units of a pumped storage power plant and guarantee safety and operation efficiency of a power system can be solved.

Description

Technical Field

[0001] The present invention relates to the technical field of power grid dispatching, and in particular to a method, device and medium for optimizing pumped storage output based on whole-plant modeling. Background Art

[0002] As an important power regulation tool, pumped storage has played an increasingly significant role in the power system in recent years. With the deepening of power market reform, pumped storage has been gradually introduced into the spot market. However, due to the increase in the proportion of renewable energy, the power system is facing increasing volatility and uncertainty, making it more difficult to balance supply and demand. In the spot market, the large-scale access of intermittent energy such as wind power and solar energy has caused the power system to often have surplus or shortage. The existing method mainly predicts the load demand of the power system to formulate the start and stop and output plan of the pumped storage power plant, so as to coordinate the dispatch of multiple units.

[0003] However, the complex market environment and real-time scheduling needs have brought huge challenges to the efficient scheduling of pumped storage resources; the frequently changing supply and demand relationships and price fluctuations in the spot market have made the optimization clearing algorithm more complicated, making it difficult to coordinate the scheduling of multiple units while ensuring system safety and operational efficiency. Summary of the invention

[0004] The present invention provides a pumped storage power output optimization method, device and medium based on whole-plant modeling to solve the problem of difficulty in coordinating and dispatching multiple units in a pumped storage power plant to ensure the safety and operation efficiency of the power system.

[0005] Obtaining operational data on power systems and pumped storage plants;

[0006] Based on the operating data, a safety-constrained unit combination is established by controlling the combination and output of the units;

[0007] Establishing a safety-constrained economic dispatch model by controlling the steady state of the pumped-storage power plant under various operating conditions;

[0008] According to the supply and demand balance requirements of each node in the power market, a node electricity price model is established;

[0009] The safety-constrained unit combination, the safety-constrained economic dispatch model and the node electricity price model are solved jointly to obtain the unit output set of the pumped-storage power plant, and the pumped-storage power plant is adjusted according to the unit output set.

[0010] The present invention is based on operating data and establishes a safety-constrained unit combination by controlling the combination and output of the units. The combination can take into account the operating characteristics of the units, load requirements, and safety constraints of the power grid, thereby optimizing the start-stop sequence and output distribution of the units and ensuring the operating efficiency of the system. By controlling the stable state of the pumped-storage power plant under various operating conditions to establish a safety-constrained economic dispatch model, the operating cost of the units, the flow constraints of the power grid, and the energy storage characteristics of the pumped-storage power plant can be comprehensively considered to achieve safe and economic dispatch of the power system. A node electricity price model is established based on the supply and demand balance requirements of each node in the power market. The model can reflect the price differences of different nodes in the power market, thereby guiding market participants to arrange power production and consumption more reasonably and achieve a balanced supply and demand relationship in the power market.

[0011] Compared with the prior art, the present invention obtains the unit output set of the pumped-storage power plant by jointly solving the combination and models of the pumped-storage power plant. The output set is the optimal solution after comprehensive consideration of multiple factors such as economy, stability and market mechanism. Therefore, by adjusting the pumped-storage power plant according to the unit output set, coordinated scheduling of multiple units can be achieved. Therefore, it is possible to solve the problem of difficulty in coordinated scheduling of multiple units in a pumped-storage power plant and ensure the safety and operation efficiency of the power system.

[0012] As a preferred solution, based on the operating data, a safety constraint unit combination is established by controlling the combination and output of the units, specifically:

[0013] Based on the operating data, a first objective function is established by minimizing the operating costs of the pumped storage power plant and the plurality of units at different time periods;

[0014] Establishing system reserve capacity constraints according to the positive reserve capacity of the pumped storage power plant at load peak or unit failure;

[0015] By limiting the number and duration of frequent starts and stops of the units, the first pumped storage power plant type operation constraints are established;

[0016] By limiting the line flow and section flow, the power grid flow constraints are established;

[0017] The safety constrained unit combination is composed of the first objective function, the system reserve capacity constraints, the first pumped storage power plant operation constraints and the power grid flow constraints.

[0018] This preferred solution establishes a first objective function so that the model can accurately calculate the operating costs of the pumped-storage power plant and several units at different times, and seeks solutions to minimize these costs, which helps to reduce the overall operating costs of the power system. Establishing system spare capacity constraints based on the positive spare capacity of the pumped-storage power plant at peak load or unit failure helps ensure that the power system can maintain a stable power supply in emergency situations and improve the reliability and stability of the system. Establishing the first pumped-storage power plant type operating constraint by limiting the number and time of frequent start-stop of the unit helps to extend the service life of the unit and reduce mechanical wear and energy loss caused by frequent start-stop. Establishing power grid flow constraints by limiting line flow and section flow can prevent problems such as power grid overload and voltage fluctuations and ensure the safe and stable operation of the power grid.

[0019] As a preferred solution, by controlling the stable state of the pumped storage power plant under various operating conditions, a safety-constrained economic dispatch model is established, specifically:

[0020] According to the operation costs of energy storage equipment and pumped storage units in different periods, a second objective function is established;

[0021] According to the frequency regulation reserve capacity of the power grid when the frequency fluctuates, the primary frequency regulation reserve capacity constraint of the first system is established;

[0022] By limiting the working time and working mode of the pumped storage units, the operation constraints of the second pumped storage power plant are established;

[0023] Establish grid operation constraints by limiting line flow to not exceed preset carrying capacity;

[0024] By limiting the output range of thermal power units, output constraints of thermal power units are established;

[0025] The safety constrained economic dispatch model is composed of the second objective function, the first system primary frequency regulation reserve capacity constraint, the second pumped storage power plant operation constraint, the power grid operation constraint and the thermal power unit output constraint.

[0026] This preferred solution establishes a first system primary frequency regulation reserve capacity constraint based on the frequency regulation reserve capacity demand of the power grid when the frequency fluctuates, which helps to ensure that the power system can adjust quickly when the frequency fluctuates and maintain the stability of the system. By limiting the working time and working mode of the pumped-storage unit, the second pumped-storage power plant operation constraint is established, which helps to extend the service life of the pumped-storage unit and reduce mechanical wear and energy loss caused by frequent start and stop or long-term operation. By limiting the line flow to not exceed the preset carrying capacity, the power grid operation constraint is established, which helps to prevent problems such as power grid overload and voltage fluctuations, and ensure the safe and stable operation of the power grid. By limiting the output range of the thermal power unit, the output constraint of the thermal power unit is established, which helps to ensure that the thermal power unit operates within a safe and economical range.

[0027] As a preferred solution, a node electricity price model is established according to the supply and demand balance requirements of each node in the power market, specifically:

[0028] The third objective function is established by introducing the network power flow constraint relaxation penalty factor to penalize the line power flow relaxation in the power market;

[0029] By setting the rapid response capacity of the pumped storage power plant during frequency fluctuations, a primary frequency regulation reserve capacity constraint of the second system is established;

[0030] According to the reservoir capacity and line flow of the pumped storage power plant, power facility operation and grid flow constraints are established; wherein the power facility operation and grid flow constraints include the first pumped storage power generation constraint, the first pumped storage capacity constraint, the line flow constraint, the section flow constraint and the upper and lower limit constraints of the conventional unit output;

[0031] The node electricity price model is composed of the third objective function, the primary frequency regulation reserve capacity constraint of the second system, and the power facility operation and grid flow constraints.

[0032] This optimization scheme introduces a network flow constraint relaxation penalty factor, so that the model can punish the line flow relaxation in the power market, thereby encouraging market participants to arrange power production and consumption more reasonably and reduce the over-limit of line flow. The node electricity price model comprehensively considers multiple factors such as the first pumped storage power generation constraint, the first pumped storage capacity constraint, the line flow constraint, the section flow constraint, and the upper and lower limit constraints of conventional unit output. The setting of these constraints helps to ensure that power facilities operate within a safe and economical range, while preventing problems such as grid overload and voltage fluctuations.

[0033] As a preferred solution, the upper and lower limits of the conventional unit output are specifically:

[0034]

[0035] Among them, P i,t represents the output of unit i in period t, and They represent the minimum and maximum output of unit i in period t, respectively. δ is the ratio of the unit allowed to deviate from the day-ahead SCED optimization result. and They are the maximum output and minimum output of the unit in the preset model respectively.

[0036] The present application also provides a pumped storage output optimization device based on whole-plant modeling, including a data module, a combination module, a safety module, an electricity price module and an adjustment module;

[0037] Wherein, the data module is used to obtain the operation data of the power system and the pumped storage power plant;

[0038] The combination module is used to establish a safety-constrained unit combination by controlling the combination and output of the units based on the operation data;

[0039] The safety module is used to establish a safety-constrained economic dispatch model by controlling the stable state of the pumped-storage power plant under various operating conditions;

[0040] The electricity price module is used to establish a node electricity price model according to the supply and demand balance requirements of each node in the electricity market;

[0041] The adjustment module is used to jointly solve the safety-constrained unit combination, the safety-constrained economic dispatch model and the node electricity price model to obtain the unit output set of the pumped-storage power plant, and adjust the pumped-storage power plant according to the unit output set.

[0042] As a preferred solution, the combination module includes a first unit, a capacity unit, an operation unit, a flow unit and a combination unit;

[0043] Wherein, the first unit is used to establish a first objective function based on the operating data by minimizing the operating costs of the pumped storage power plant and the plurality of units at different time periods;

[0044] The capacity unit is used to establish a system reserve capacity constraint according to the positive reserve capacity of the pumped storage power plant at load peak or unit failure;

[0045] The operation unit is used to establish a first pumped storage power plant type operation constraint by limiting the number and duration of frequent starts and stops of the unit;

[0046] The power flow unit is used to establish power grid power flow constraints by limiting line power flow and section power flow;

[0047] The combination unit is used to form the safety constraint unit combination by using the first objective function, the system reserve capacity type constraint, the first pumped storage power plant type operation constraint and the power grid flow type constraint.

[0048] As a preferred solution, the safety module includes a second unit, a frequency modulation unit, a pumping unit, a power grid unit, an output unit and a constituent unit;

[0049] Wherein, the second unit is used to establish a second objective function according to the operating costs of the energy storage device and the pumped storage unit in different time periods;

[0050] The frequency regulation unit is used to establish a primary frequency regulation reserve capacity constraint of the first system according to the frequency regulation reserve capacity of the power grid when the frequency fluctuates;

[0051] The pumping unit is used to establish the second pumped-storage power plant operation class constraint by limiting the working time and working mode of the pumped-storage unit;

[0052] The power grid unit is used to establish power grid operation constraints by limiting the line flow to not exceed a preset carrying capacity;

[0053] The output unit is used to establish output constraints of the thermal power unit by limiting the output range of the thermal power unit;

[0054] The constituent unit is used to form the security constraint economic dispatch model by means of the second objective function, the first system primary frequency regulation reserve capacity constraint, the second pumped storage power plant operation constraint, the power grid operation constraint and the thermal power unit output constraint.

[0055] As a preferred solution, the electricity price module includes a third unit, a frequency unit, a facility unit and a summary unit;

[0056] The third unit is used to penalize the line power flow relaxation amount in the power market by introducing a network power flow constraint relaxation penalty factor to establish a third objective function;

[0057] The frequency unit is used to establish a second system primary frequency regulation reserve capacity constraint by setting a fast response capacity of the pumped storage power plant when the frequency fluctuates;

[0058] The facility unit is used to establish power facility operation and grid flow constraints according to the reservoir capacity and line flow of the pumped storage power plant; wherein the power facility operation and grid flow constraints include the first pumped storage power generation constraint, the first pumped storage capacity constraint, the line flow constraint, the section flow constraint and the upper and lower limit constraints of the conventional unit output;

[0059] The summarizing unit is used to form the node electricity price model by using the third objective function, the primary frequency regulation reserve capacity constraint of the second system and the power facility operation and grid flow constraints.

[0060] As a preferred solution, the upper and lower limits of the conventional unit output are specifically:

[0061]

[0062] Among them, P i,t represents the output of unit i in period t, and They represent the minimum and maximum output of unit i in period t, respectively. δ is the ratio of the unit allowed to deviate from the day-ahead SCED optimization result. and They are the maximum output and minimum output of the unit in the preset model respectively.

[0063] The present application also provides a storage medium having a computer program stored thereon, the computer program being called and executed by a computer to implement the above-mentioned method for optimizing pumped storage output based on whole-plant modeling. BRIEF DESCRIPTION OF THE DRAWINGS

[0064] Figure 1 It is a flow chart of a method for optimizing pumped storage power output based on whole-plant modeling provided in an embodiment of the present application;

[0065] Figure 2 It is a data flow diagram provided by an embodiment of the present application;

[0066] Figure 3 It is a structural schematic diagram of a pumped storage output optimization device based on whole-plant modeling provided in an embodiment of the present application. DETAILED DESCRIPTION

[0067] The following will be combined with the drawings in the embodiments of the present application to clearly and completely describe the technical solutions in the embodiments of the present application. Obviously, the described embodiments are only part of the embodiments of the present application, not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of this application.

[0068] In the description of the present application, it should be understood that the terms "first", "second" and "third" are used for descriptive purposes only and should not be understood as indicating or implying relative importance or implicitly indicating the number of technical features indicated. Thus, features defined as "first", "second" and "third" may explicitly or implicitly include one or more of the features. In the description of the present application, unless otherwise specified, "several" means two or more.

[0069] The embodiment of the present application provides a pumped storage power output optimization method based on whole-plant modeling, which is mainly used in situations where the flexibility and economy of unit scheduling need to be improved, and the overall safety and coordination of the system need to be ensured, so that pumped storage power plants can achieve efficient participation and optimized clearing in the spot market, thereby improving system operating efficiency.

[0070] Embodiment 1:

[0071] See also Figure 1 The embodiment of the present application provides a method for optimizing pumped storage output based on whole-plant modeling, including S1 to S5, and the specific implementation steps are as follows:

[0072] S1. Obtain the operating data of the power system and pumped storage power plant.

[0073] Step S1 of the embodiment of the present application is specifically as follows:

[0074] Monitor the operating status of the power system and pumped storage power plant, including parameters such as voltage, frequency and power flow, and obtain the operating data of the power system and pumped storage power plant;

[0075] Verify and validate the collected operational data to ensure its accuracy, completeness and consistency.

[0076] S2. Based on the operating data, establish a safe and constrained unit combination by controlling the combination and output of the units.

[0077] Step S2 of the embodiment of the present application is specifically as follows:

[0078] Based on the operating data, the first objective function F1 is established by minimizing the operating costs of the pumped storage power plant and several units at different times;

[0079] According to the positive reserve capacity of the pumped storage power plant at load peak or unit failure, establish system reserve capacity constraints; including system positive reserve capacity constraints, system negative reserve capacity constraints and third system primary frequency regulation reserve capacity constraints;

[0080] By limiting the number and time of frequent start and stop of the unit, the first pumped storage power plant type operation constraint is established; wherein, the first pumped storage power plant type operation constraint includes the pumped storage power plant ramp constraint expression, the pumped power constraint of the pumped storage power plant, the pumped capacity constraint of the pumped storage power plant, the minimum continuous start time constraint of the pumped storage power plant, the minimum continuous pump start time constraint of the pumped storage power plant, the minimum continuous shutdown time constraint of the pumped storage power plant and the start and stop number limit of the pumped storage power plant;

[0081] By limiting the line flow and the section flow, a power grid flow constraint is established; wherein the power grid flow constraint includes a first line flow constraint and a first section flow constraint;

[0082] The safety constrained unit combination is composed of the first objective function F1, system reserve capacity constraints, the first pumped storage power plant operation constraints and power grid flow constraints.

[0083] Among them, the first objective function is:

[0084]

[0085] Among them, N represents the total number of conventional units, including non-market units and market units, excluding new energy storage trading units and pumped storage units; T represents the total number of time periods considered, where D day has a time period of 15 minutes, 96 time periods are considered, and D+1 day considers two time periods of load peak and trough, so T is 98; P i,t represents the output of unit i in time period t; M represents the network power flow constraint relaxation penalty factor used for market clearing optimization; and They represent the forward power flow slack variable and the reverse power flow slack variable of line l respectively, and NL is the total number of lines; and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of section s respectively, NS is the total number of sections; ES is the total number of energy storage trading units, C es,t (P es,t ) represents the operating cost of energy storage es in time period t; PP represents the number of optimization units of pumped storage power plant, each optimization unit is composed of units with the same grid-connected node in the power plant, C pp,t (P pp,t ) represents the operating cost of the pumped storage power plant pp in time period t;

[0086] C i,t (P i,t ), and They represent the operating cost, startup cost and minimum stable technical output cost of unit i in period t, among which the unit operating cost C i,t (P i,t) is a multi-segment linear function related to the output ranges reported by the unit and the corresponding energy prices; unit startup cost It is a function related to the downtime of the unit, which represents the startup cost of the unit in different states (cold / warm / hot); minimum stable technical output cost The period when the unit is turned on is included in the calculation.

[0087] The specific constraints in the safety constraint unit combination are:

[0088] ① System positive reserve capacity constraints:

[0089]

[0090] Among them, NF represents the number of thermal power units, α f,t represents the start and stop status of unit f in period t, α f,t =0 means the unit is shut down, α f,t =1 means the unit is on; is the maximum output of unit f in period t; represents the single unit capacity of the pumped storage power plant pp in time period t, T j,t represents the planned power of tie line j in time period t (input is positive, output is negative), NT is the total number of tie lines, represents the maximum number of operating units in the pumped storage power plant, NH represents the number of conventional hydropower units, is the capacity of conventional hydropower unit h in time period t, Indicates the deduction value of unstable output of the unit in time period t; It represents the system positive reserve capacity requirement for time period t. In normal period, it must also meet the reserve requirement of the highest load point on day D+1. In special periods such as tight power supply, the power dispatching agency can start the special period operation reserve as required.

[0091] ② System negative reserve capacity constraints:

[0092]

[0093] in, represents the minimum output of unit f in period t, represents the rated pumping power of a single unit of the pumped storage power plant pp in time period t, Indicates the maximum number of pumps in operation in a pumped storage power plant. Indicates the minimum output of conventional hydroelectric units, represents the system negative reserve capacity requirement for time period t.

[0094] ③ Constraints on the primary frequency regulation reserve capacity of the third system:

[0095]

[0096] in, It represents the system primary frequency regulation reserve capacity requirement for time period t; and They represent the primary frequency regulation reserve capacity provided by thermal power unit i, pumped storage power plant pp and hydropower unit h (including only the running units) in time period t respectively;

[0097] For parameters and have:

[0098]

[0099]

[0100] in, P represents the available capacity of the pumped storage power plant pp in time period t, which is the maximum number of units in operation multiplied by the capacity of a single unit; f,t and They represent the optimal output and maximum capacity of the thermal power unit i in time period t, respectively. pp,t represents the optimal output of the pumped storage power plant pp in time period t, P h,t and They respectively represent the optimized output and maximum startup capacity provided by the hydropower unit h (including only the startup units) in time period t.

[0101] ④ Pumped storage power plant ramp constraint expression:

[0102]

[0103] in, represents the power generation of the power plant in time period t, represents the pumping power of the power plant in time period t, represents the single unit capacity of the pumped storage power plant pu in time period t, Indicates the power generation ramp-up rate of the power plant in time period t, the value is UTS pp The sum of the capacities of 100 pumped storage units, with no limit on ramping during power generation; It represents the pumping ramp rate of the power plant in time period t. The value is the deviation of the corresponding adjacent gears. Pumping ramp is not restricted.

[0104] ⑤ Constraints on the extraction power of pumped storage power plants:

[0105]

[0106]

[0107] For parameters have:

[0108]

[0109] in, It indicates the rated pumping power of the power plant at gear g. The power of each gear is the accumulated rated pumping power of the power plant including the units according to the quotations from low to high. and They represent the maximum power generation and the minimum power generation respectively. The maximum power generation is the sum of the maximum power generation of the units in the power plant, and the minimum power generation is the smaller value of the minimum power generation of the units in the plant. and A 0-1 integer variable representing the pumping state of a pumped storage power plant, 1 means the pump is on, 0 means the pump is off; is the power generation during time period t.

[0110] ⑥ Pumped storage power plant capacity constraints:

[0111]

[0112] in, and represents the upper and lower storage capacity of the pumped storage power station pp (m 3 ), Indicates the conversion efficiency of pumped reservoir capacity to electricity (m 3 / MWh); Indicates the power conversion efficiency of the power generation capacity (m 3 / MWh), the conversion efficiency is the same as that of a single machine; Δt represents the duration of each period;

[0113] and They represent the upper storage capacity and lower storage capacity of the pumped storage power station in time period t respectively; and They represent the minimum upper storage capacity, maximum upper storage capacity, minimum lower storage capacity and maximum lower storage capacity of the pumped storage power station in time period t, and the values ​​are the upper and lower limits of the upper and lower storage capacities, respectively. In addition, the power dispatching agency shall set the upper and lower limits of storage capacity at the end of each day according to the needs of power grid security and power supply, which shall not exceed the upper and lower limits of storage capacity of the pumped storage power station, and shall be disclosed as private information before 12:00 on the bidding day (D-1 day).

[0114] ⑦ Constraints on the minimum continuous operation time of pumped storage power plants:

[0115]

[0116] in, Indicates the minimum continuous operation time of the pumped storage power plant. The value is the same as the time of a single machine. Indicates from the time period The sum of the power generation status of the pumped storage power plant up to t-1.

[0117] ⑧ Minimum continuous pump start time constraints for pumped storage power plants:

[0118]

[0119] in, Indicates the minimum continuous pump-on time of a pumped-storage power plant, the value is the same as the time of a single unit; Indicates from the time period The sum of the pumping status of the pumped storage power plant up to t-1 (a 0-1 integer variable).

[0120] ⑨ Constraints on minimum continuous downtime of pumped storage power plants:

[0121]

[0122] in, Indicates the minimum continuous downtime of a pumped-storage power plant, and its value is the same as that of a single unit.

[0123] ⑩Restrictions on the number of starts and stops of pumped storage power plants:

[0124]

[0125] Among them, β pp,t and γ pp,t Represents the startup and shutdown variables of the pumped storage power plant; UDTS pp It indicates the maximum start and stop times of a pumped-storage power plant, which is equal to the sum of the maximum start and stop times of all pumped-storage units in the plant.

[0126] First line power flow constraint:

[0127]

[0128] Among them, P pp,t is the output of the pumped storage power plant pp in time period t, P l max represents the power transmission limit of line l, G l-i G represents the generator output power transfer distribution factor of the node where unit i is located to line l, l-j G represents the power transfer distribution factor of the generator output at the node of tie line j to line l. l-e is the sensitivity factor of node e to line l; ES is the number of energy storage units, and They represent the discharge and charging power of the energy storage unit, K represents the number of nodes in the system, G l-krepresents the generator output power transfer distribution factor of node k to line l, G l-p represents the power transfer distribution factor of the generator output from node p to line l where the pumping transaction unit pp is located, D u,t represents the bus load value of bus u in time period t, and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of line l respectively.

[0129] First section flow constraint:

[0130]

[0131] Among them, P s min and P s max They represent the lower limit and upper limit of power flow transmission of section s, respectively. s-i G represents the generator output power transfer distribution factor of the node where unit i is located to section s, s-e G represents the power transfer distribution factor of the generator output at the node where the energy storage es is located to the section s. s-j G represents the power transfer distribution factor of the generator output at the node j of the tie line to the section s. s-p G represents the power transfer distribution factor of the generator output at the node p to the section s where the pumping transaction unit pp is located. s-k represents the generator output power transfer distribution factor of node k to section s, and They represent the forward flow relaxation variable and reverse flow relaxation variable of section s respectively.

[0132] This embodiment S2 establishes a first objective function so that the model can accurately calculate the operating costs of the pumped-storage power plant and several units at different time periods, and seeks a solution to minimize these costs, which helps to reduce the overall operating cost of the power system. Establishing a system spare capacity constraint based on the positive spare capacity of the pumped-storage power plant at peak load or unit failure helps to ensure that the power system can still maintain a stable power supply in emergency situations and improve the reliability and stability of the system. Establishing a first pumped-storage power plant-type operating constraint by limiting the number and time of frequent start-stops of the unit helps to extend the service life of the unit and reduce mechanical wear and energy consumption losses caused by frequent start-stops. Establishing a power grid flow constraint by limiting line flow and section flow can prevent problems such as power grid overload and voltage fluctuations, and ensure the safe and stable operation of the power grid.

[0133] S3. Establish a safety-constrained economic dispatch model by controlling the stable state of the pumped-storage power plant under various operating conditions.

[0134] Step S3 of the embodiment of the present application is specifically as follows:

[0135] According to the operating costs of the energy storage equipment and the pumped storage unit in different periods, the second objective function F2 is established;

[0136] According to the frequency regulation reserve capacity of the power grid when the frequency fluctuates, the primary frequency regulation reserve capacity constraint of the first system is established;

[0137] By limiting the working time and working mode of the pumped-storage units, the operation constraints of the second pumped-storage power plant are established; among which, the operation constraints of the second pumped-storage power plant include the second pumped-storage power generation constraint, the second pumped-storage reservoir capacity constraint, the maximum and minimum number of units started of the pumped-storage unit group, the minimum continuous start-up time constraint of pumped-storage, the minimum continuous pump start-up time constraint of pumped-storage, the minimum continuous shutdown time constraint of pumped-storage, the same pumping and discharge constraint of pumped-storage units in the same plant, the limit on the number of additional pumps started of pumped-storage units in the same plant, and the limit on the number of starts and stops of pumped-storage units;

[0138] By limiting the line flow not to exceed the preset carrying capacity, a power grid operation constraint is established; wherein the power grid operation constraint includes a second line flow constraint and a second section flow constraint;

[0139] By limiting the output range of thermal power units, output constraints of thermal power units are established;

[0140] The safety constrained economic dispatch model is composed of the second objective function F2, the primary frequency regulation reserve capacity constraint of the first system, the second pumped storage power plant operation constraint, the power grid operation constraint and the thermal power unit output constraint.

[0141] Among them, the second objective function is:

[0142]

[0143] Among them, N represents the total number of conventional units, including non-market units and market units, excluding new energy storage trading units and pumped storage units; T represents the total number of time periods considered, where D day has a time period of 15 minutes, 96 time periods are considered, and D+1 day considers two time periods of load peak and trough, so T is 98; P i,t represents the output of unit i in period t; C i,t (P i,t ) represents the operating cost of unit i in period t, and the unit operating cost C i,t (P i,t ) is a multi-segment linear function related to the output intervals reported by the unit and the corresponding energy prices; M represents the network power flow constraint relaxation penalty factor used for market clearing optimization; and They represent the forward power flow slack variable and the reverse power flow slack variable of line l respectively, and NL is the total number of lines; and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of section s respectively, NS is the total number of sections; ES is the total number of energy storage trading units, C es,t (P es,t ) represents the operating cost of energy storage es in time period t; PU represents the number of pumped storage units, C pu,t (P pu,t ) represents the operating cost of the pumped storage unit pu in time period t.

[0144] The specific constraints in the safety-constrained economic dispatch model are:

[0145] ① Constraints on the primary frequency regulation reserve capacity of the first system:

[0146]

[0147] in, It represents the system primary frequency regulation reserve capacity requirement for time period t; and They represent the primary frequency regulation reserve capacity provided by thermal power unit i, pumped storage power plant pp and hydropower unit h (including only the running units) in time period t respectively;

[0148] For parameters and have:

[0149]

[0150] in, It represents the operating capacity of pumped storage power plant p in time period t.

[0151] ② Second pumped storage power generation constraints:

[0152]

[0153] in, Indicates the rated pumping power of the unit. is the generating power of the unit in period t, and Indicates the maximum power generation and the minimum power generation; and A 0-1 integer variable representing the pumping state of the pumped storage unit. 1 means the pump is on, and 0 means the pump is off.

[0154] ③ Second pumped storage capacity constraints:

[0155]

[0156] in, represents the rated pumping power of the unit in time period t, and represents the upper and lower storage capacity of the pumped storage power station pp (m 3 ), PP represents the number of pumped storage units in the power station, Indicates the conversion efficiency of pumped reservoir capacity to electricity (m 3 / MWh), Indicates the power conversion efficiency of the power generation capacity (m 3 / MWh), Δt represents the duration of each period, and They represent the minimum upper storage capacity, maximum upper storage capacity, minimum lower storage capacity and maximum lower storage capacity of the pumped storage power station in time period t, PPU pp Indicates the number of pumped storage units included in the pumped storage power plant pp.

[0157] ④ Constraints on the maximum and minimum number of pumped storage units in operation:

[0158] The number of units in the pumped storage group should be within a given range, and its constraints can be described as:

[0159]

[0160] in, and are the maximum and minimum number of started units of pumped storage generator group j in time period t, respectively.

[0161] ⑤ Constraints on the minimum continuous operation time of pumped storage:

[0162]

[0163] in, Indicates the minimum continuous start-up time of the pumped storage unit. Indicates the maximum continuous operating time of the pumped storage unit.

[0164] ⑥ Constraints on the minimum continuous pumping time for pumped storage:

[0165]

[0166] in, Indicates the minimum continuous pump-on time of the pumped-storage unit.

[0167] ⑦ Constraints on minimum continuous downtime of pumped storage:

[0168]

[0169] in, Indicates the minimum continuous downtime of the pumped storage unit.

[0170] ⑧ Constraints on simultaneous pumping and discharging of pumped storage units in the same plant:

[0171]

[0172] ⑨Restriction on the number of additional pumps for pumped storage units in the same plant:

[0173]

[0174] Among them, PTS pp Indicates the maximum number of pumps that can be operated simultaneously in a pumped storage power plant, UTS pp Indicates the maximum number of units that can be started simultaneously in a pumped-storage power plant.

[0175] ⑩Restrictions on the number of starts and stops of pumped storage units:

[0176]

[0177] Among them, β pu,t and γ pu,t They represent the startup and shutdown variables of the pumped storage unit, UDTS pu Indicates the maximum number of starts and stops of the pumped storage unit.

[0178] Second line power flow constraint:

[0179]

[0180] Among them, P l max represents the power transmission limit of line l, G l-i G represents the generator output power transfer distribution factor of the node where unit i is located to line l, l-j G represents the power transfer distribution factor of the generator output at the node of tie line j to line l. l-e is the sensitivity factor of node e to line l, K represents the number of nodes in the system, G l-k represents the generator output power transfer distribution factor of node k to line l, G l-p represents the generator output power transfer distribution factor of the node p where the pumped storage unit pu is located to the line l, D u,t represents the bus load value of bus u in time period t, and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of line l respectively.

[0181] The second section flow constraint:

[0182] Considering the flow constraint of the key section, the constraint can be described as:

[0183]

[0184] Among them, P s min and P s max They represent the lower limit and upper limit of power flow transmission of section s, respectively. s-i G represents the generator output power transfer distribution factor of the node where unit i is located to section s, s-e G represents the power transfer distribution factor of the generator output at the node where the energy storage es is located to the section s. s-j G represents the power transfer distribution factor of the generator output at the node j of the tie line to the section s. s-p G represents the generator output power transfer distribution factor of the node p where the pumped storage unit pu is located to the section s, s-k represents the generator output power transfer distribution factor of node k to section s, and They represent the forward flow relaxation variable and reverse flow relaxation variable of section s respectively.

[0185] Output constraints of thermal power units:

[0186] The output of the unit should be within its maximum / minimum output range, and its constraints can be described as:

[0187]

[0188] Among them, for the units that are shut down in the SCUC optimization results, and The average value is zero.

[0189] This embodiment S3 establishes a first system primary frequency regulation reserve capacity constraint according to the frequency regulation reserve capacity demand of the power grid when the frequency fluctuates, which helps to ensure that the power system can adjust quickly when the frequency fluctuates and maintain the stability of the system. By limiting the working time and working mode of the pumped-storage unit, the second pumped-storage power plant operation constraint is established, which helps to extend the service life of the pumped-storage unit and reduce the mechanical wear and energy loss caused by frequent start and stop or long-term operation. By limiting the line flow to not exceed the preset carrying capacity, the power grid operation constraint is established, which helps to prevent the occurrence of problems such as power grid overload and voltage fluctuations, and ensure the safe and stable operation of the power grid. By limiting the output range of the thermal power unit, the output constraint of the thermal power unit is established, which helps to ensure that the thermal power unit operates within a safe and economical range.

[0190] S4. Establish a node electricity price model based on the supply and demand balance requirements of each node in the power market.

[0191] Step S4 of the embodiment of the present application is specifically as follows:

[0192] The third objective function F3 is established by introducing a network power flow constraint relaxation penalty factor to penalize the line power flow relaxation in the power market;

[0193] By setting the rapid response capacity of the pumped storage power plant during frequency fluctuations, the primary frequency regulation reserve capacity constraint of the second system is established;

[0194] Based on the reservoir capacity and line flow of the pumped storage power plant, power facility operation and grid flow constraints are established; among them, power facility operation and grid flow constraints include the first pumped storage power generation constraint, the first pumped storage capacity constraint, line flow constraint, section flow constraint and conventional unit output upper and lower limit constraints;

[0195] The node power price (LPC) model is composed of the third objective function F3, the primary frequency regulation reserve capacity constraint of the second system, and the power facility operation and grid flow constraints.

[0196] Among them, the third objective function is:

[0197]

[0198] Among them, N represents the total number of conventional units, including non-market units and market units, excluding new energy storage trading units and pumped storage units; T represents the total number of time periods considered, where D day has a time period of 15 minutes, 96 time periods are considered, and D+1 day considers two time periods of load peak and trough, so T is 98; P i,t represents the output of unit i in period t; C i,t (P i,t ) represents the operating cost of unit i in period t, and the unit operating cost C i,t (P i,t ) is a multi-segment linear function related to each output interval reported by the unit and the corresponding energy price; M' represents the network power flow constraint relaxation penalty factor used for node power price calculation; and They represent the forward power flow slack variable and the reverse power flow slack variable of line l respectively, and NL is the total number of lines; and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of section s respectively, NS is the total number of sections; ES is the total number of energy storage trading units, C es,t (P es,t ) represents the operating cost of energy storage es in time period t; PU represents the number of pumped storage units, C pu,t (Ppu,t ) represents the operating cost of the pumped storage unit pu in time period t.

[0199] The constraints in the node electricity price model are as follows:

[0200] ① Constraints on the primary frequency regulation reserve capacity of the second system:

[0201]

[0202] in, It represents the system primary frequency regulation reserve capacity requirement for time period t; and They represent the primary frequency regulation reserve capacity provided by thermal power unit i, pumped storage power plant pp and hydropower unit h (including only the running units) in time period t respectively;

[0203] For parameters and have:

[0204]

[0205] in, It represents the operating capacity of the pumped storage power plant pp in time period t.

[0206] ② The first pumped storage power generation constraint:

[0207]

[0208] in, Indicates the rated pumping power of the unit. and Represent the maximum power generation and the minimum power generation respectively; and A 0-1 integer variable representing the pumping state of the pumped storage unit, 1 means the pump is on / started, and 0 means the pump is off / stopped;

[0209] If the unit is shut down, the unit output can be limited to 0 through this constraint; when the unit is started, the constraint is the conventional upper and lower limit constraint of the output.

[0210] ③The first pumped storage capacity constraint:

[0211]

[0212] in, and represents the upper and lower storage capacity of the pumped storage power station pp (m 3 ), PP represents the number of pumped storage units in the power station, Indicates the conversion efficiency of pumped reservoir capacity to electricity (m 3 / MWh), Indicates the power conversion efficiency of the power generation capacity (m 3 / MWh), Δt represents the duration of each period, and They represent the minimum upper storage capacity, maximum upper storage capacity, minimum lower storage capacity and maximum lower storage capacity of the pumped storage power station in time period t, PPU pp Indicates the number of pumped storage units included in the pumped storage power plant pp.

[0213] ④Line flow constraints:

[0214]

[0215] Among them, P l max represents the power transmission limit of line l, G l-i G represents the generator output power transfer distribution factor of the node where unit i is located to line l, l-j G represents the power transfer distribution factor of the generator output at the node of tie line j to line l. l-e is the sensitivity factor of node e to line l, K represents the number of nodes in the system, G l-k represents the generator output power transfer distribution factor of node k to line l, G l-p represents the generator output power transfer distribution factor of the node p where the pumped storage unit pu is located to the line l, D u,t represents the bus load value of bus u in time period t, and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of line l respectively.

[0216] ⑤ Sectional flow constraints:

[0217]

[0218] Among them, P s min and P s max They represent the lower limit and upper limit of power flow transmission of section s, respectively. s-i G represents the generator output power transfer distribution factor of the node where unit i is located to section s, s-e G represents the power transfer distribution factor of the generator output at the node where the energy storage es is located to the section s. s-j G represents the power transfer distribution factor of the generator output at the node j of the tie line to the section s. s-p G represents the generator output power transfer distribution factor of the node p where the pumped storage unit pu is located to the section s, s-k represents the generator output power transfer distribution factor of node k to section s, and They represent the forward flow relaxation variable and reverse flow relaxation variable of section s respectively.

[0219] ⑥Conventional unit output upper and lower limit constraints:

[0220] The output of the unit should be within its maximum / minimum output range, and its constraints can be described as:

[0221]

[0222] For the units that are shut down in the SCUC optimization results, and are all taken as zero; for non-priceable units, The winning bid output of unit i in time period t in the SCED optimization result is taken as

[0223] For priced units, and Take the following values:

[0224]

[0225] Among them, P i,t represents the output of unit i in period t, and They represent the minimum and maximum output of unit i in period t, respectively. δ is the ratio of the unit allowed to deviate from the day-ahead SCED optimization result. and They are the maximum output and minimum output of the unit in the preset model respectively.

[0226] In this embodiment S4, by introducing a network flow constraint relaxation penalty factor, the model can punish the line flow relaxation in the power market, thereby encouraging market participants to arrange power production and consumption more reasonably and reduce the over-limit of line flow. The node electricity price model comprehensively considers multiple factors such as the first pumped storage power generation constraint, the first pumped storage capacity constraint, the line flow constraint, the section flow constraint, and the upper and lower limit constraints of the conventional unit output. The setting of these constraints helps to ensure that the power facilities operate within a safe and economical range, while preventing the occurrence of problems such as grid overload and voltage fluctuation.

[0227] S5. Solve the safety-constrained unit combination, the safety-constrained economic dispatch model and the node electricity price model jointly to obtain the unit output set of the pumped-storage power plant, and adjust the pumped-storage power plant according to the unit output set.

[0228] Step S5 of the embodiment of the present application is specifically as follows:

[0229] Solve the safety constraint unit combination to obtain the start and stop status of the thermal power unit;

[0230] Substitute the start and stop states of thermal power units into the safety-constrained economic dispatch model, and solve it in combination with the safety-constrained unit commitment and node electricity price model to obtain the unit output set of the pumped-storage power plant.

[0231] The pumped storage power plant is adjusted according to the unit output set.

[0232] To apply the embodiments of this application, please refer to Figure 2 , Figure 2 is a data flow chart provided in an embodiment of the present application, which shows the general process of obtaining the optimization result in the first embodiment of the present application;

[0233] It can be seen that in the safety constrained unit commitment (SCUC) stage, the whole plant modeling method is used to carry out overall dispatch of pumped storage, ensuring the safety of the system while reducing the cross-section limit, which significantly improves the efficiency and safety of dispatch. In the safety constrained economic dispatch (SCED) stage, the single-unit output of pumped storage is further optimized to achieve refined dispatch. Subsequently, the unit combination results of the SCED stage are input into the node power price (LPC) model to obtain the optimized unit output for adjustment. This method not only improves the overall operating efficiency, but also effectively solves the dispatch difficulties in the spot market, and promotes the efficient participation and optimized clearing of pumped storage.

[0234] Overall, this embodiment has the following beneficial effects:

[0235] This application is based on operating data and establishes a safety-constrained unit combination by controlling the combination and output of the units. This combination can take into account the operating characteristics of the units, load demand, and safety constraints of the power grid, thereby optimizing the start and stop sequence and output distribution of the units and ensuring the operating efficiency of the system. By controlling the stable state of the pumped-storage power plant under various operating conditions to establish a safety-constrained economic dispatch model, it is possible to comprehensively consider the operating costs of the units, the flow constraints of the power grid, and the energy storage characteristics of the pumped-storage power plant to achieve safe and economic dispatch of the power system. A node electricity price model is established based on the supply and demand balance requirements of each node in the electricity market. This model can reflect the differences in electricity prices at different nodes in the electricity market, thereby guiding market participants to arrange electricity production and consumption more reasonably and achieve a balanced supply and demand relationship in the electricity market;

[0236] By jointly solving the combination and models of pumped-storage power plants, the unit output set of the pumped-storage power plant is obtained. This output set is the optimal solution after comprehensive consideration of multiple factors such as economy, stability and market mechanism. Therefore, by adjusting the pumped-storage power plant according to the unit output set, coordinated scheduling of multiple units can be achieved. Therefore, it is possible to solve the problem of difficulty in coordinated scheduling of multiple units in pumped-storage power plants and ensure the safety and operation efficiency of the power system.

[0237] Embodiment 2:

[0238] See also Figure 3 , the embodiment of the present application provides a pumped storage output optimization device based on whole-plant modeling, including a data module 10, a combination module 20, a safety module 30, an electricity price module 40 and an adjustment module 50;

[0239] Wherein, the data module 10 is used to obtain the operation data of the power system and the pumped storage power plant;

[0240] A combination module 20, for establishing a safety-constrained unit combination by controlling the combination and output of the units based on the operation data;

[0241] A safety module 30 for establishing a safety-constrained economic dispatch model by controlling the steady state of the pumped storage power plant under various operating conditions;

[0242] The electricity price module 40 is used to establish a node electricity price model according to the supply and demand balance requirements of each node in the electricity market;

[0243] The adjustment module 50 is used to jointly solve the safety-constrained unit combination, the safety-constrained economic dispatch model and the node electricity price model to obtain the unit output set of the pumped-storage power plant and adjust the pumped-storage power plant according to the unit output set.

[0244] In one embodiment, the data module 10 is specifically:

[0245] Monitor the operating status of the power system and pumped storage power plant, including parameters such as voltage, frequency and power flow, and obtain the operating data of the power system and pumped storage power plant;

[0246] Verify and validate the collected operational data to ensure its accuracy, completeness and consistency.

[0247] In one embodiment, the combination module 20 includes a first unit, a capacity unit, an operation unit, a flow unit, and a combination unit;

[0248] The first unit is used to establish a first objective function F1 based on the operation data by minimizing the operation costs of the pumped storage power plant and several units in different time periods;

[0249] The capacity unit is used to establish system reserve capacity constraints according to the positive reserve capacity of the pumped storage power plant at load peak or unit failure; including system positive reserve capacity constraints, system negative reserve capacity constraints and third system primary frequency regulation reserve capacity constraints;

[0250] An operation unit is used to establish a first pumped-storage power plant type operation constraint by limiting the number and time of frequent start and stop of the unit; wherein the first pumped-storage power plant type operation constraint includes a pumped-storage power plant ramp constraint expression, a pumped-storage power plant extraction power constraint, a pumped-storage power plant storage capacity constraint, a pumped-storage power plant minimum continuous start time constraint, a pumped-storage power plant minimum continuous pump start time constraint, a pumped-storage power plant minimum continuous stop time constraint and a pumped-storage power plant start and stop number limit;

[0251] A power flow unit, used to establish power grid power flow constraints by limiting line power flow and section power flow; wherein the power grid power flow constraints include a first line power flow constraint and a first section power flow constraint;

[0252] The combination unit is used to form a safety constraint unit combination based on the first objective function F1, system reserve capacity constraints, first pumped storage power plant operation constraints and power grid flow constraints.

[0253] Among them, the first objective function is:

[0254]

[0255] Among them, N represents the total number of conventional units, including non-market units and market units, excluding new energy storage trading units and pumped storage units; T represents the total number of time periods considered, where D day has a time period of 15 minutes, 96 time periods are considered, and D+1 day considers two time periods of load peak and trough, so T is 98; P i,t represents the output of unit i in time period t; M represents the network power flow constraint relaxation penalty factor used for market clearing optimization; and They represent the forward power flow slack variable and the reverse power flow slack variable of line l respectively, and NL is the total number of lines; and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of section s respectively, NS is the total number of sections; ES is the total number of energy storage trading units, C es,t (P es,t ) represents the operating cost of energy storage es in time period t; PP represents the number of optimization units of pumped storage power plant, each optimization unit is composed of units with the same grid-connected node in the power plant, C pp,t (P pp,t ) represents the operating cost of the pumped storage power plant pp in time period t;

[0256] C i,t (P i,t ), and They represent the operating cost, startup cost and minimum stable technical output cost of unit i in period t, among which the unit operating cost C i,t(P i,t ) is a multi-segment linear function related to the output ranges reported by the unit and the corresponding energy prices; unit startup cost It is a function related to the downtime of the unit, which represents the startup cost of the unit in different states (cold / warm / hot); minimum stable technical output cost The period when the unit is turned on is included in the calculation.

[0257] The specific constraints in the safety constraint unit combination are:

[0258] ① System positive reserve capacity constraints:

[0259]

[0260] Among them, NF represents the number of thermal power units, α f,t represents the start and stop status of unit f in period t, α f,t =0 means the unit is shut down, α f,t =1 means the unit is on; is the maximum output of unit f in period t; represents the single unit capacity of the pumped storage power plant pp in time period t, T j,t represents the planned power of tie line j in time period t (input is positive, output is negative), NT is the total number of tie lines, represents the maximum number of operating units in the pumped storage power plant, NH represents the number of conventional hydropower units, is the capacity of conventional hydropower unit h in time period t, Indicates the deduction value of unstable output of the unit in time period t; It represents the system positive reserve capacity requirement for time period t. In normal period, it must also meet the reserve requirement of the highest load point on day D+1. In special periods such as tight power supply, the power dispatching agency can start the special period operation reserve as required.

[0261] ② System negative reserve capacity constraints:

[0262]

[0263] in, represents the minimum output of unit f in period t, represents the rated pumping power of a single unit of the pumped storage power plant pp in time period t, Indicates the maximum number of pumps in operation in a pumped storage power plant. Indicates the minimum output of conventional hydroelectric units, represents the system negative reserve capacity requirement for time period t.

[0264] ③ Constraints on the primary frequency regulation reserve capacity of the third system:

[0265]

[0266] in, It represents the system primary frequency regulation reserve capacity requirement for time period t; and They represent the primary frequency regulation reserve capacity provided by thermal power unit i, pumped storage power plant pp and hydropower unit h (including only the running units) in time period t respectively;

[0267] For parameters and have:

[0268]

[0269] in, P represents the available capacity of the pumped storage power plant pp in time period t, which is the maximum number of units in operation multiplied by the capacity of a single unit; f,t and They represent the optimal output and maximum capacity of the thermal power unit i in time period t, respectively. pp,t represents the optimal output of the pumped storage power plant pp in time period t, P h,t and They respectively represent the optimized output and maximum startup capacity provided by the hydropower unit h (including only the startup units) in time period t.

[0270] ④ Pumped storage power plant ramp constraint expression:

[0271]

[0272]

[0273] in, represents the power generation of the power plant in time period t, represents the pumping power of the power plant in time period t, represents the single unit capacity of the pumped storage power plant pu in time period t, Indicates the power generation ramp-up rate of the power plant in time period t, the value is UTS pp The sum of the capacities of 100 pumped storage units, with no limit on ramping during power generation; It represents the pumping ramp rate of the power plant in time period t. The value is the deviation of the corresponding adjacent gears. Pumping ramp is not restricted.

[0274] ⑤ Constraints on the extraction power of pumped storage power plants:

[0275]

[0276] For parameters have:

[0277]

[0278] in, It indicates the rated pumping power of the power plant at gear g. The power of each gear is the accumulated rated pumping power of the power plant including the units according to the quotations from low to high. and They represent the maximum power generation and the minimum power generation respectively. The maximum power generation is the sum of the maximum power generation of the units in the power plant, and the minimum power generation is the smaller value of the minimum power generation of the units in the plant. and A 0-1 integer variable representing the pumping state of a pumped storage power plant, 1 means the pump is on, 0 means the pump is off; is the power generation during time period t.

[0279] ⑥ Pumped storage power plant capacity constraints:

[0280]

[0281] in, and represents the upper and lower storage capacity of the pumped storage power station pp (m 3 ), Indicates the conversion efficiency of pumped reservoir capacity to electricity (m 3 / MWh); Indicates the power conversion efficiency of the power generation capacity (m 3 / MWh), the conversion efficiency is the same as that of a single machine; Δt represents the duration of each period;

[0282] and They represent the upper storage capacity and lower storage capacity of the pumped storage power station in time period t respectively; and They represent the minimum upper storage capacity, maximum upper storage capacity, minimum lower storage capacity and maximum lower storage capacity of the pumped storage power station in time period t, and the values ​​are the upper and lower limits of the upper and lower storage capacities, respectively. In addition, the power dispatching agency shall set the upper and lower limits of storage capacity at the end of each day according to the needs of power grid security and power supply, which shall not exceed the upper and lower limits of the storage capacity of the pumped storage power station, and shall be disclosed as private information before 12:00 on the bidding day (D-1 day).

[0283] ⑦ Constraints on the minimum continuous operation time of pumped storage power plants:

[0284]

[0285] in, Indicates the minimum continuous operation time of the pumped storage power plant. The value is the same as the time of a single machine. Indicates from the time period The sum of the power generation status of the pumped storage power plant up to t-1.

[0286] ⑧ Minimum continuous pump start time constraints for pumped storage power plants:

[0287]

[0288] in, Indicates the minimum continuous pump-on time of a pumped-storage power plant, the value is the same as the time of a single unit; Indicates from the time period The sum of the pumping status of the pumped storage power plant up to t-1 (a 0-1 integer variable).

[0289] ⑨ Constraints on minimum continuous downtime of pumped storage power plants:

[0290]

[0291] in, Indicates the minimum continuous downtime of a pumped-storage power plant, and its value is the same as that of a single unit.

[0292] ⑩Restrictions on the number of starts and stops of pumped storage power plants:

[0293]

[0294] Among them, β pp,t and γ pp,t Represents the startup and shutdown variables of the pumped storage power plant; UDTS pp It indicates the maximum start and stop times of a pumped-storage power plant, which is equal to the sum of the maximum start and stop times of all pumped-storage units in the plant.

[0295] First line power flow constraint:

[0296]

[0297] Among them, P pp,t is the output of the pumped storage power plant pp in time period t, P l max represents the power transmission limit of line l, G l-i G represents the generator output power transfer distribution factor of the node where unit i is located to line l, l-j G represents the power transfer distribution factor of the generator output at the node of tie line j to line l. l-e is the sensitivity factor of node e to line l; ES is the number of energy storage units, and They represent the discharge and charging power of the energy storage unit, K represents the number of nodes in the system, G l-krepresents the generator output power transfer distribution factor of node k to line l, G l-p represents the power transfer distribution factor of the generator output from node p to line l where the pumping transaction unit pp is located, D u,t represents the bus load value of bus u in time period t, and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of line l respectively.

[0298] First section flow constraint:

[0299]

[0300] Among them, P s min and P s max They represent the lower limit and upper limit of power flow transmission of section s, respectively. s-i G represents the generator output power transfer distribution factor of the node where unit i is located to section s, s-e G represents the power transfer distribution factor of the generator output at the node where the energy storage es is located to the section s. s-j G represents the power transfer distribution factor of the generator output at the node j of the tie line to the section s. s-p G represents the power transfer distribution factor of the generator output at the node p to the section s where the pumping transaction unit pp is located. s-k represents the generator output power transfer distribution factor of node k to section s, and They represent the forward flow relaxation variable and reverse flow relaxation variable of section s respectively.

[0301] The combined module 20 of this embodiment establishes a first objective function so that the model can accurately calculate the operating costs of the pumped-storage power plant and several units at different time periods, and seeks solutions to minimize these costs, which helps to reduce the overall operating costs of the power system. Establishing system spare capacity constraints based on the positive spare capacity of the pumped-storage power plant at peak load or unit failure helps to ensure that the power system can still maintain a stable power supply in emergency situations and improve the reliability and stability of the system. Establishing the first pumped-storage power plant type operating constraints by limiting the number and time of frequent start-stop of the unit helps to extend the service life of the unit and reduce mechanical wear and energy consumption losses caused by frequent start-stop. Establishing power grid flow constraints by limiting line flow and section flow can prevent problems such as power grid overload and voltage fluctuations and ensure the safe and stable operation of the power grid.

[0302] In one embodiment, the safety module 30 includes a second unit, a frequency modulation unit, a pumping unit, a grid unit, an output unit, and a constituent unit;

[0303] The second unit is used to establish a second objective function F2 according to the operating costs of the energy storage equipment and the pumped storage unit in different periods of time;

[0304] A frequency regulation unit, used for establishing a primary frequency regulation reserve capacity constraint of the first system according to the frequency regulation reserve capacity of the power grid when the frequency fluctuates;

[0305] The pumping unit is used to establish the operation constraints of the second pumped-storage power plant by limiting the working time and working mode of the pumped-storage units; wherein the operation constraints of the second pumped-storage power plant include the second pumped-storage power generation constraint, the second pumped-storage reservoir capacity constraint, the maximum and minimum number of units started up for the pumped-storage unit group, the minimum continuous start-up time constraint for pumped-storage, the minimum continuous pump start-up time constraint for pumped-storage, the minimum continuous shutdown time constraint for pumped-storage, the same pumping and discharge constraint for pumped-storage units in the same plant, the limit on the number of additional pumps started up for pumped-storage units in the same plant, and the limit on the number of starts and stops of pumped-storage units;

[0306] A power grid unit, used to establish power grid operation constraints by limiting the line flow to not exceed a preset carrying capacity; wherein the power grid operation constraints include a second line flow constraint and a second section flow constraint;

[0307] Output unit, used to establish output constraints of thermal power units by limiting the output range of thermal power units;

[0308] The constituent unit is used to form a safety constrained economic dispatch model by the second objective function F2, the primary frequency regulation reserve capacity constraint of the first system, the operation constraint of the second pumped storage power plant, the operation constraint of the power grid and the output constraint of the thermal power unit.

[0309] Among them, the second objective function is:

[0310]

[0311] Among them, N represents the total number of conventional units, including non-market units and market units, excluding new energy storage trading units and pumped storage units; T represents the total number of time periods considered, where D day has a time period of 15 minutes, 96 time periods are considered, and D+1 day considers two time periods of load peak and trough, so T is 98; P i,t represents the output of unit i in period t; C i,t (P i,t ) represents the operating cost of unit i in period t, and the unit operating cost C i,t (P i,t ) is a multi-segment linear function related to the output intervals reported by the unit and the corresponding energy prices; M represents the network power flow constraint relaxation penalty factor used for market clearing optimization; and They represent the forward power flow slack variable and the reverse power flow slack variable of line l respectively, and NL is the total number of lines; and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of section s respectively, NS is the total number of sections; ES is the total number of energy storage trading units, C es,t (P es,t ) represents the operating cost of energy storage es in time period t; PU represents the number of pumped storage units, C pu,t (P pu,t ) represents the operating cost of the pumped storage unit pu in time period t.

[0312] The specific constraints in the safety-constrained economic dispatch model are:

[0313] ① Constraints on the primary frequency regulation reserve capacity of the first system:

[0314]

[0315] in, It represents the system primary frequency regulation reserve capacity requirement for time period t; and They represent the primary frequency regulation reserve capacity provided by thermal power unit i, pumped storage power plant pp and hydropower unit h (including only the running units) in time period t respectively;

[0316] For parameters and have:

[0317]

[0318] in, It represents the operating capacity of pumped storage power plant p in time period t.

[0319] ② Second pumped storage power generation constraints:

[0320]

[0321]

[0322] in, Indicates the rated pumping power of the unit. is the generating power of the unit in period t, and Indicates the maximum power generation and the minimum power generation; and A 0-1 integer variable representing the pumping state of the pumped storage unit. 1 means the pump is on, and 0 means the pump is off.

[0323] ③ Second pumped storage capacity constraints:

[0324]

[0325] in, represents the rated pumping power of the unit in time period t, and represents the upper and lower storage capacity of the pumped storage power station pp (m 3 ), PP represents the number of pumped storage units in the power station, Indicates the conversion efficiency of pumped reservoir capacity to electricity (m 3 / MWh), Indicates the power conversion efficiency of the power generation capacity (m 3 / MWh), Δt represents the duration of each period, and They represent the minimum upper storage capacity, maximum upper storage capacity, minimum lower storage capacity and maximum lower storage capacity of the pumped storage power station in time period t, PPU pp Indicates the number of pumped storage units included in the pumped storage power plant pp.

[0326] ④ Constraints on the maximum and minimum number of pumped storage units in operation:

[0327] The number of units in the pumped storage group should be within a given range, and its constraints can be described as:

[0328]

[0329] in, and are the maximum and minimum number of started units of pumped storage generator group j in time period t, respectively.

[0330] ⑤ Constraints on the minimum continuous operation time of pumped storage:

[0331]

[0332] in, Indicates the minimum continuous start-up time of the pumped storage unit. Indicates the maximum continuous operating time of the pumped storage unit.

[0333] ⑥ Constraints on the minimum continuous pumping time for pumped storage:

[0334]

[0335] in, Indicates the minimum continuous pump-on time of the pumped-storage unit.

[0336] ⑦ Constraints on minimum continuous downtime of pumped storage:

[0337]

[0338] in, Indicates the minimum continuous downtime of the pumped storage unit.

[0339] ⑧ Constraints on simultaneous pumping and discharging of pumped storage units in the same plant:

[0340]

[0341] ⑨Restriction on the number of additional pumps for pumped storage units in the same plant:

[0342]

[0343] Among them, PTS pp Indicates the maximum number of pumps that can be operated simultaneously in a pumped storage power plant, UTS pp Indicates the maximum number of units that can be started simultaneously in a pumped-storage power plant.

[0344] ⑩Restrictions on the number of starts and stops of pumped storage units:

[0345]

[0346] Among them, β pu,t and γ pu,t They represent the startup and shutdown variables of the pumped storage unit, UDTS pu Indicates the maximum number of starts and stops of the pumped storage unit.

[0347] Second line power flow constraint:

[0348]

[0349] Among them, P l max represents the power transmission limit of line l, G l-i G represents the generator output power transfer distribution factor of the node where unit i is located to line l, l-j G represents the power transfer distribution factor of the generator output at the node of tie line j to line l. l-e is the sensitivity factor of node e to line l, K represents the number of nodes in the system, G l-k represents the generator output power transfer distribution factor of node k to line l, G l-p represents the generator output power transfer distribution factor of the node p where the pumped storage unit pu is located to the line l, D u,t represents the bus load value of bus u in time period t, and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of line l respectively.

[0350] The second section flow constraint:

[0351] Considering the flow constraint of the key section, the constraint can be described as:

[0352]

[0353] Among them, P s min and P s max They represent the lower limit and upper limit of power flow transmission of section s, respectively. s-i G represents the generator output power transfer distribution factor of the node where unit i is located to section s, s-e G represents the power transfer distribution factor of the generator output at the node where the energy storage es is located to the section s. s-j G represents the power transfer distribution factor of the generator output at the node j of the tie line to the section s. s-p G represents the generator output power transfer distribution factor of the node p where the pumped storage unit pu is located to the section s, s-k represents the generator output power transfer distribution factor of node k to section s, and They represent the forward flow relaxation variable and reverse flow relaxation variable of section s respectively.

[0354] Output constraints of thermal power units:

[0355] The output of the unit should be within its maximum / minimum output range, and its constraints can be described as:

[0356]

[0357] Among them, for the units that are shut down in the SCUC optimization results, and The average value is zero.

[0358] This embodiment S3 establishes a first system primary frequency regulation reserve capacity constraint according to the frequency regulation reserve capacity demand of the power grid when the frequency fluctuates, which helps to ensure that the power system can adjust quickly when the frequency fluctuates and maintain the stability of the system. By limiting the working time and working mode of the pumped-storage unit, the second pumped-storage power plant operation constraint is established, which helps to extend the service life of the pumped-storage unit and reduce the mechanical wear and energy loss caused by frequent start and stop or long-term operation. By limiting the line flow to not exceed the preset carrying capacity, the power grid operation constraint is established, which helps to prevent the occurrence of problems such as power grid overload and voltage fluctuations, and ensure the safe and stable operation of the power grid. By limiting the output range of the thermal power unit, the output constraint of the thermal power unit is established, which helps to ensure that the thermal power unit operates within a safe and economical range.

[0359] In one embodiment, the electricity price module 40 includes a third unit, a frequency unit, a facility unit, and a summary unit;

[0360] The third unit is used to penalize the line power flow relaxation amount in the power market by introducing a network power flow constraint relaxation penalty factor, and establish a third objective function F3;

[0361] The frequency unit is used to establish the primary frequency regulation reserve capacity constraint of the second system by setting the rapid response capacity of the pumped storage power plant when the frequency fluctuates;

[0362] The facility unit is used to establish power facility operation and grid flow constraints based on the reservoir capacity and line flow of the pumped storage power plant; wherein the power facility operation and grid flow constraints include the first pumped storage power generation constraint, the first pumped storage capacity constraint, the line flow constraint, the section flow constraint, and the upper and lower limit constraints of the conventional unit output;

[0363] The summarizing unit is used to form a node power price (LPC) model by using the third objective function F3, the primary frequency regulation reserve capacity constraint of the second system, and the power facility operation and power grid flow constraints.

[0364] Among them, the third objective function is:

[0365]

[0366] Among them, N represents the total number of conventional units, including non-market units and market units, excluding new energy storage trading units and pumped storage units; T represents the total number of time periods considered, where D day has a time period of 15 minutes, 96 time periods are considered, and D+1 day considers two time periods of load peak and trough, so T is 98; P i,t represents the output of unit i in period t; C i,t (P i,t ) represents the operating cost of unit i in period t, and the unit operating cost C i,t (P i,t ) is a multi-segment linear function related to each output interval reported by the unit and the corresponding energy price; M' represents the network power flow constraint relaxation penalty factor used for node power price calculation; and They represent the forward power flow slack variable and the reverse power flow slack variable of line l respectively, and NL is the total number of lines; and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of section s respectively, NS is the total number of sections; ES is the total number of energy storage trading units, C es,t (P es,t ) represents the operating cost of energy storage es in time period t; PU represents the number of pumped storage units, Cpu,t (P pu,t ) represents the operating cost of the pumped storage unit pu in time period t.

[0367] The constraints in the node electricity price model are as follows:

[0368] ① Constraints on the primary frequency regulation reserve capacity of the second system:

[0369]

[0370] in, It represents the system primary frequency regulation reserve capacity requirement for time period t; and They represent the primary frequency regulation reserve capacity provided by thermal power unit i, pumped storage power plant pp and hydropower unit h (including only the running units) in time period t respectively;

[0371] For parameters and have:

[0372]

[0373] in, It represents the operating capacity of the pumped storage power plant pp in time period t.

[0374] ② The first pumped storage power generation constraint:

[0375]

[0376] in, Indicates the rated pumping power of the unit. and Represent the maximum power generation and the minimum power generation respectively; and A 0-1 integer variable representing the pumping state of the pumped storage unit, 1 means the pump is on / started, and 0 means the pump is off / stopped;

[0377] If the unit is shut down, the unit output can be limited to 0 through this constraint; when the unit is started, the constraint is the conventional upper and lower limit constraint of the output.

[0378] ③The first pumped storage capacity constraint:

[0379]

[0380] in, and represents the upper and lower storage capacity of the pumped storage power station pp (m 3 ), PP represents the number of pumped storage units in the power station, Indicates the conversion efficiency of pumped reservoir capacity to electricity (m3 / MWh), Indicates the power conversion efficiency of the power generation capacity (m 3 / MWh), Δt represents the duration of each period, and They represent the minimum upper storage capacity, maximum upper storage capacity, minimum lower storage capacity and maximum lower storage capacity of the pumped storage power station in time period t, PPU pp Indicates the number of pumped storage units included in the pumped storage power plant pp.

[0381] ④Line flow constraints:

[0382]

[0383] Among them, P l max represents the power transmission limit of line l, G l-i G represents the generator output power transfer distribution factor of the node where unit i is located to line l, l-j G represents the power transfer distribution factor of the generator output at the node of tie line j to line l. l-e is the sensitivity factor of node e to line l, K represents the number of nodes in the system, G l-k represents the generator output power transfer distribution factor of node k to line l, G l-p represents the generator output power transfer distribution factor of the node p where the pumped storage unit pu is located to the line l, D u,t represents the bus load value of bus u in time period t, and They represent the forward power flow relaxation variable and reverse power flow relaxation variable of line l respectively.

[0384] ⑤ Sectional flow constraints:

[0385]

[0386] Among them, P s min and P s max They represent the lower limit and upper limit of power flow transmission of section s, respectively. s-i G represents the generator output power transfer distribution factor of the node where unit i is located to section s, s-e G represents the power transfer distribution factor of the generator output at the node where the energy storage es is located to the section s. s-j G represents the power transfer distribution factor of the generator output at the node j of the tie line to the section s. s-p G represents the generator output power transfer distribution factor of the node p where the pumped storage unit pu is located to the section s, s-krepresents the generator output power transfer distribution factor of node k to section s, and They represent the forward flow relaxation variable and reverse flow relaxation variable of section s respectively.

[0387] ⑥Conventional unit output upper and lower limit constraints:

[0388] The output of the unit should be within its maximum / minimum output range, and its constraints can be described as:

[0389]

[0390] For the units that are shut down in the SCUC optimization results, and are all taken as zero; for non-priceable units, The winning bid output of unit i in time period t in the SCED optimization result is taken as

[0391] For priced units, and Take the following values:

[0392]

[0393] Among them, P i,t represents the output of unit i in period t, and They represent the minimum and maximum output of unit i in period t, respectively. δ is the ratio of the unit allowed to deviate from the day-ahead SCED optimization result. and They are the maximum output and minimum output of the unit in the preset model respectively.

[0394] In this embodiment S4, by introducing a network flow constraint relaxation penalty factor, the model can punish the line flow relaxation in the power market, thereby encouraging market participants to arrange power production and consumption more reasonably and reduce the over-limit of line flow. The node electricity price model comprehensively considers multiple factors such as the first pumped storage power generation constraint, the first pumped storage capacity constraint, the line flow constraint, the section flow constraint, and the upper and lower limit constraints of the conventional unit output. The setting of these constraints helps to ensure that the power facilities operate within a safe and economical range, while preventing the occurrence of problems such as grid overload and voltage fluctuation.

[0395] In one embodiment, the adjustment module 50 is specifically:

[0396] Solve the safety constraint unit combination to obtain the start and stop status of the thermal power unit;

[0397] Substitute the start and stop states of thermal power units into the safety-constrained economic dispatch model, and solve it in combination with the safety-constrained unit commitment and node electricity price model to obtain the unit output set of the pumped-storage power plant.

[0398] The pumped storage power plant is adjusted according to the unit output set.

[0399] To apply the embodiments of this application, please refer to Figure 2 , Figure 2 is a data flow chart provided in the embodiment of the present application, which shows the general process of obtaining the optimization result in the second embodiment of the present application;

[0400] It can be seen that in the safety constrained unit commitment (SCUC) stage, the whole plant modeling method is used to carry out overall dispatch of pumped storage, ensuring the safety of the system while reducing the cross-section limit, which significantly improves the efficiency and safety of dispatch. In the safety constrained economic dispatch (SCED) stage, the single-unit output of pumped storage is further optimized to achieve refined dispatch. Subsequently, the unit combination results of the SCED stage are input into the node power price (LPC) model to obtain the optimized unit output for adjustment. This method not only improves the overall operating efficiency, but also effectively solves the dispatch difficulties in the spot market, and promotes the efficient participation and optimized clearing of pumped storage.

[0401] Overall, this embodiment has the following beneficial effects:

[0402] This application is based on operating data and establishes a safety-constrained unit combination by controlling the combination and output of the units. This combination can take into account the operating characteristics of the units, load demand, and safety constraints of the power grid, thereby optimizing the start and stop sequence and output distribution of the units and ensuring the operating efficiency of the system. By controlling the stable state of the pumped-storage power plant under various operating conditions to establish a safety-constrained economic dispatch model, it is possible to comprehensively consider the operating costs of the units, the flow constraints of the power grid, and the energy storage characteristics of the pumped-storage power plant to achieve safe and economic dispatch of the power system. A node electricity price model is established based on the supply and demand balance requirements of each node in the electricity market. This model can reflect the differences in electricity prices at different nodes in the electricity market, thereby guiding market participants to arrange electricity production and consumption more reasonably and achieve a balanced supply and demand relationship in the electricity market;

[0403] By jointly solving the combination and models of pumped-storage power plants, the unit output set of the pumped-storage power plant is obtained. This output set is the optimal solution after comprehensive consideration of multiple factors such as economy, stability and market mechanism. Therefore, by adjusting the pumped-storage power plant according to the unit output set, coordinated scheduling of multiple units can be achieved. Therefore, it is possible to solve the problem of difficulty in coordinated scheduling of multiple units in pumped-storage power plants and ensure the safety and operation efficiency of the power system.

[0404] Embodiment three:

[0405] The embodiment of the present application provides a computer-readable storage medium, the computer-readable storage medium includes a stored computer program, wherein when the computer program is running, the device where the computer-readable storage medium is located is controlled to execute the pumped storage power output optimization method based on whole-plant modeling;

[0406] Wherein, the pumped storage output optimization method based on the whole plant modeling, if implemented in the form of a software functional unit and used as an independent product, can be stored in a computer-readable storage medium. Based on such an understanding, the present invention implements all or part of the processes in the above-mentioned embodiment method, and can also be completed by instructing the relevant hardware through a computer program. The computer program can be stored in a computer-readable storage medium, and the computer program can implement the steps of the above-mentioned various method embodiments when executed by the processor. Wherein, the computer program includes computer program code, and the computer program code can be in source code form, object code form, executable file or some intermediate form, etc. The computer-readable medium may include: any entity or device capable of carrying the computer program code, recording medium, U disk, mobile hard disk, disk, optical disk, computer memory, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), electric carrier signal, telecommunication signal and software distribution medium, etc.

[0407] The above are preferred embodiments of the present invention. It should be noted that, for ordinary technicians in this technical field, several improvements and modifications can be made without departing from the principles of the present invention. These improvements and modifications are also considered to be within the scope of protection of the present invention.

Claims

1. A method for optimizing pumped storage output based on whole-plant modeling, characterized in that: include: Obtaining operational data on power systems and pumped storage plants; Based on the operating data, a safety-constrained unit combination is established by controlling the combination and output of the units; Establishing a safety-constrained economic dispatch model by controlling the steady state of the pumped-storage power plant under various operating conditions; According to the supply and demand balance requirements of each node in the power market, a node electricity price model is established; The safety-constrained unit combination, the safety-constrained economic dispatch model and the node electricity price model are solved jointly to obtain the unit output set of the pumped-storage power plant, and the pumped-storage power plant is adjusted according to the unit output set.

2. A method for optimizing pumped storage output based on whole-plant modeling as claimed in claim 1, characterized in that: Based on the operating data, a safety constraint unit combination is established by controlling the combination and output of the units, specifically: Based on the operating data, a first objective function is established by minimizing the operating costs of the pumped storage power plant and the plurality of units at different time periods; Establishing system reserve capacity constraints according to the positive reserve capacity of the pumped storage power plant at load peak or unit failure; By limiting the number and duration of frequent starts and stops of the units, the first pumped storage power plant type operation constraints are established; By limiting the line flow and section flow, the power grid flow constraints are established; The safety constrained unit combination is composed of the first objective function, the system reserve capacity constraints, the first pumped storage power plant operation constraints and the power grid flow constraints.

3. A method for optimizing pumped storage output based on plant-wide modeling as claimed in claim 1, characterized in that: By controlling the stable state of the pumped storage power plant under various operating conditions, a safety-constrained economic dispatch model is established, specifically: According to the operation costs of energy storage equipment and pumped storage units in different periods, a second objective function is established; According to the frequency regulation reserve capacity of the power grid when the frequency fluctuates, the primary frequency regulation reserve capacity constraint of the first system is established; By limiting the working time and working mode of the pumped storage units, the operation constraints of the second pumped storage power plant are established; Establish grid operation constraints by limiting line flow to not exceed preset carrying capacity; By limiting the output range of thermal power units, output constraints of thermal power units are established; The safety constrained economic dispatch model is composed of the second objective function, the first system primary frequency regulation reserve capacity constraint, the second pumped storage power plant operation constraint, the power grid operation constraint and the thermal power unit output constraint.

4. A method for optimizing pumped storage output based on whole-plant modeling as claimed in claim 1, characterized in that: According to the supply and demand balance requirements of each node in the power market, a node electricity price model is established, specifically: The third objective function is established by introducing the network power flow constraint relaxation penalty factor to penalize the line power flow relaxation in the power market; By setting the rapid response capacity of the pumped storage power plant during frequency fluctuations, a primary frequency regulation reserve capacity constraint of the second system is established; According to the reservoir capacity and line flow of the pumped storage power plant, power facility operation and grid flow constraints are established; wherein the power facility operation and grid flow constraints include the first pumped storage power generation constraint, the first pumped storage capacity constraint, the line flow constraint, the section flow constraint and the upper and lower limit constraints of the conventional unit output; The node electricity price model is composed of the third objective function, the primary frequency regulation reserve capacity constraint of the second system, and the power facility operation and grid flow constraints.

5. A method for optimizing pumped storage output based on whole-plant modeling as claimed in claim 4, characterized in that: The conventional unit output upper and lower limit constraints are specifically: Among them, P i,t represents the output of unit i in period t, and They represent the minimum and maximum output of unit i in period t, respectively. δ is the ratio of the unit allowed to deviate from the day-ahead SCED optimization result. and They are the maximum output and minimum output of the unit in the preset model respectively.

6. A pumped storage output optimization device based on whole plant modeling, characterized in that: It includes data module, combination module, security module, electricity price module and adjustment module; Wherein, the data module is used to obtain the operation data of the power system and the pumped storage power plant; The combination module is used to establish a safety-constrained unit combination by controlling the combination and output of the units based on the operation data; The safety module is used to establish a safety-constrained economic dispatch model by controlling the stable state of the pumped-storage power plant under various operating conditions; The electricity price module is used to establish a node electricity price model according to the supply and demand balance requirements of each node in the electricity market; The adjustment module is used to jointly solve the safety-constrained unit combination, the safety-constrained economic dispatch model and the node electricity price model to obtain the unit output set of the pumped-storage power plant, and adjust the pumped-storage power plant according to the unit output set.

7. A pumped storage power output optimization device based on whole plant modeling as claimed in claim 6, characterized in that: The combined module includes a first unit, a capacity unit, an operation unit, a flow unit and a combined unit; Wherein, the first unit is used to establish a first objective function based on the operating data by minimizing the operating costs of the pumped storage power plant and the plurality of units at different time periods; The capacity unit is used to establish a system reserve capacity constraint according to the positive reserve capacity of the pumped storage power plant at load peak or unit failure; The operation unit is used to establish a first pumped storage power plant type operation constraint by limiting the number and duration of frequent starts and stops of the unit; The power flow unit is used to establish power grid power flow constraints by limiting line power flow and section power flow; The combination unit is used to form the safety constraint unit combination by using the first objective function, the system reserve capacity type constraint, the first pumped storage power plant type operation constraint and the power grid flow type constraint.

8. A pumped storage power output optimization device based on whole plant modeling as claimed in claim 6, characterized in that: The safety module includes a second unit, a frequency modulation unit, a pumping unit, a power grid unit, an output unit and a constituent unit; Wherein, the second unit is used to establish a second objective function according to the operating costs of the energy storage device and the pumped storage unit in different time periods; The frequency regulation unit is used to establish a primary frequency regulation reserve capacity constraint of the first system according to the frequency regulation reserve capacity of the power grid when the frequency fluctuates; The pumping unit is used to establish the second pumped-storage power plant operation class constraint by limiting the working time and working mode of the pumped-storage unit; The power grid unit is used to establish power grid operation constraints by limiting the line flow to not exceed a preset carrying capacity; The output unit is used to establish output constraints of the thermal power unit by limiting the output range of the thermal power unit; The constituent unit is used to form the security constraint economic dispatch model by means of the second objective function, the first system primary frequency regulation reserve capacity constraint, the second pumped storage power plant operation constraint, the power grid operation constraint and the thermal power unit output constraint.

9. A pumped storage power output optimization device based on whole plant modeling as claimed in claim 6, characterized in that: The electricity price module includes a third unit, a frequency unit, a facility unit and a summary unit; The third unit is used to penalize the line power flow relaxation amount in the power market by introducing a network power flow constraint relaxation penalty factor to establish a third objective function; The frequency unit is used to establish a second system primary frequency regulation reserve capacity constraint by setting a fast response capacity of the pumped storage power plant when the frequency fluctuates; The facility unit is used to establish power facility operation and grid flow constraints according to the reservoir capacity and line flow of the pumped storage power plant; wherein the power facility operation and grid flow constraints include the first pumped storage power generation constraint, the first pumped storage capacity constraint, the line flow constraint, the section flow constraint and the upper and lower limit constraints of the conventional unit output; The summarizing unit is used to form the node electricity price model by using the third objective function, the primary frequency regulation reserve capacity constraint of the second system and the power facility operation and grid flow constraints.

10. A storage medium, characterized in that: The storage medium stores a computer program, which is called and executed by a computer to implement a pumped storage power output optimization method based on whole-plant modeling as described in any one of claims 1 to 5 above.

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