A method, device and equipment for allocating capacity cost of a pumped storage power station at user side

Abstract

The application discloses a method, device and equipment for allocating pumped storage power station capacity cost on the user side, and relates to the field of capacity cost allocation. The method comprises solving a time sequence production simulation model to obtain an optimal solution; based on the optimal solution, different allocation mechanisms are used to respectively determine the allocation results of the pumped storage power station capacity cost on the user side in the first scenario of the pumped storage power station serving a single regional power grid, the second scenario of the pumped storage power station serving multiple regional power grids, the third scenario of the pumped storage power station serving a new energy station and a single regional power grid, and the fourth scenario of the pumped storage power station serving a new energy station and multiple regional power grids. The allocation mechanisms are determined according to a capacity electricity cost recovery mechanism, a benefit sharing mechanism, a user flat allocation mechanism, a voltage level allocation mechanism, an allocation mode among regional power grids, an allocation mode between a new energy station and a power system, and an allocation mode between a photovoltaic station and a wind power station. The application can fairly and reasonably allocate the pumped storage capacity electricity cost on the user side.

Description

Technical Field

[0001] The present application relates to the field of capacity cost sharing, and in particular to a method, device and equipment for sharing the capacity cost of a pumped storage power station on the user side. Background Art

[0002] In recent years, renewable energy has been continuously integrated into the power system on a large scale and at a high rate, placing higher demands on the system's flexible adjustment capabilities. Pumped storage, currently the most mature energy storage technology, has garnered widespread attention and experienced explosive growth as a primary means of enhancing power system flexibility. Because the construction cost of pumped storage power stations (PSs) accounts for a significant proportion of the total cost, large-scale construction of these stations will also generate significant capacity charges.

[0003] Currently, the capacity electricity charges for pumped-storage power plants are determined using an operating period pricing method. This not only ensures full recovery of capacity costs but also, by benchmarking against leading industries, provides plants with an annual internal rate of return of 6.5%. While the current mechanism effectively ensures the recovery of capacity costs for pumped-storage power plants, the corresponding capacity electricity charges are ultimately passed on to users, leading to higher electricity prices for industrial and commercial users, causing complaints from some users and ultimately impacting the efficiency of capacity cost recovery for pumped-storage power plants. The lack of a comprehensive method for allocating capacity electricity charges to users has become a major constraint on the large-scale development of pumped-storage power plants.

[0004] Currently, there is limited research on methods for allocating and channeling capacity charges for pumped-storage power stations. Most research focuses on two aspects: first, determining the allocation ratio of capacity charges for pumped-storage power stations across multiple regional power grids (such as provincial power grids) based on the functions and service performance of the pumped-storage power stations; and second, clarifying the allocation ratio of capacity charges for pumped-storage power stations between renewable energy stations and the power system based on relevant standards. Regardless of the proportion of capacity charges for pumped-storage power stations allocated across multiple regional power grids and between renewable energy stations and the power grid, the portion borne by the grid will ultimately be passed on to industrial and commercial users within the region. Without a relatively comprehensive allocation method on the user side, the cost recovery efficiency of the power station will ultimately be low, which will affect the investment confidence of social capital and, to a certain extent, hinder the construction and development of pumped-storage power stations.

[0005] With the successive commissioning of pumped-storage power stations, they will face huge pressure to recover capacity costs in the future. How to improve the allocation plan of capacity costs of pumped-storage power stations on the user side and improve the fairness and rationality of the allocation of capacity electricity charges on the user side has become an urgent problem to be solved. Summary of the Invention

[0006] The purpose of this application is to provide a method, device and equipment for allocating the capacity cost of a pumped-storage power station on the user side, which can fairly and reasonably allocate and guide the pumped-storage capacity electricity fee on the user side, which can not only reduce the allocation pressure on the user side, but also effectively improve the cost recovery efficiency of the pumped-storage power station.

[0007] To achieve the above objectives, this application provides the following solutions:

[0008] In a first aspect, the present application provides a method for allocating capacity costs of a pumped storage power station on the user side, comprising:

[0009] Determine service scenarios for the pumped storage power station; the service scenarios include: a first scenario, a second scenario, a third scenario, and a fourth scenario; the first scenario is that the pumped storage power station serves a single regional power grid; the second scenario is that the pumped storage power station serves multiple regional power grids; the third scenario is that the pumped storage power station serves a new energy station and a single regional power grid; the fourth scenario is that the pumped storage power station serves a new energy station and multiple regional power grids;

[0010] Constructing a time-series production simulation model; the time-series production simulation model includes: an objective function and constraints; the objective function is constructed with the goal of maximizing the absorption capacity of the pumped-storage power station for the new energy station; the constraints include: power balance constraints, system capacity constraints, system external power constraints, new energy station output constraints, thermal power unit output constraints, thermal power unit ramp rate constraints, hydropower unit output constraints, pumped-storage unit output constraints, and pumped-storage power station storage capacity constraints;

[0011] Solving the time-series production simulation model to obtain an optimal solution; the optimal solution includes: the output of the pumped-storage unit and the output of the new energy station when the pumped-storage power station has the maximum capacity to absorb the new energy station;

[0012] When the service scenario of the pumped storage power station is the first scenario, based on the optimal solution, a first allocation mechanism is adopted to determine the allocation result of the capacity cost of the pumped storage power station on the user side; the first allocation mechanism is determined according to a capacity electricity fee recovery mechanism, a revenue sharing mechanism, a user equalization mechanism, and an allocation mechanism based on voltage level;

[0013] When the service scenario of the pumped storage power station is the second scenario, a second allocation mechanism is used to determine the allocation result of the capacity fee of the pumped storage power station on the user side; the second allocation mechanism is determined based on the allocation method of the capacity electricity fee among the regional power grid, the user equalization mechanism, and the allocation mechanism based on voltage level;

[0014] when the service scenario of the pumped storage power station is the third scenario, based on the optimal solution, a third allocation mechanism is used to determine the allocation result of the capacity cost of the pumped storage power station on the user side; the third allocation mechanism is determined according to the allocation mode of the capacity electricity fee between the new energy station and the power system, the allocation mode of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station, and the first allocation mechanism;

[0015] when the service scenario of the pumped storage power station is the fourth scenario, based on the optimal solution, a fourth allocation mechanism is used to determine the allocation result of the capacity cost of the pumped storage power station on the user side; the fourth allocation mechanism is determined according to the allocation mode of the capacity electricity fee between the new energy station and the power system, the allocation mode of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station, and the second allocation mechanism.

[0016] In a second aspect, the present application provides a device for allocating the capacity cost of a pumped storage power station on the user side, comprising:

[0017] a service scenario determination module configured to determine a service scenario of a pumped storage power station; the service scenario comprises a first scenario, a second scenario, a third scenario and a fourth scenario; the first scenario is that the pumped storage power station serves a single regional power grid; the second scenario is that the pumped storage power station serves multiple regional power grids; the third scenario is that the pumped storage power station serves a new energy station and a single regional power grid; the fourth scenario is that the pumped storage power station serves a new energy station and multiple regional power grids;

[0018] a simulation model construction module configured to construct a time-series production simulation model; the time-series production simulation model comprises an objective function and a constraint condition; the objective function is constructed with the maximum consumption of the new energy station by the pumped storage power station as the target; the constraint condition comprises power balance constraint, system capacity constraint, system external power constraint, new energy station output constraint, thermal power unit output constraint, thermal power unit climbing rate constraint, hydropower unit output constraint, pumped storage unit output constraint and pumped storage power station storage capacity constraint;

[0019] a solution module configured to solve the time-series production simulation model to obtain an optimal solution; the optimal solution comprises the output of the pumped storage unit and the output of the new energy station when the maximum consumption of the new energy station by the pumped storage power station is achieved;

[0020] a first allocation module configured to, when the service scenario of the pumped storage power station is the first scenario, based on the optimal solution, use a first allocation mechanism to determine the allocation result of the capacity cost of the pumped storage power station on the user side; the first allocation mechanism is determined according to a capacity electricity fee recovery mechanism, a revenue sharing mechanism, a user flat allocation mechanism and a voltage level allocation mechanism;

[0021] A second allocation module is configured to, when the service scenario of the pumped-storage power station is the second scenario, determine the allocation result of the capacity cost of the pumped-storage power station on the user side using a second allocation mechanism; the second allocation mechanism is determined based on the allocation method of the capacity electricity fee among regional power grids, the user equalization mechanism, and the voltage level allocation mechanism;

[0022] A third allocation module is configured to, when the service scenario of the pumped-storage power station is the third scenario, determine, based on the optimal solution, a result of allocating the capacity fee of the pumped-storage power station on the user side using a third allocation mechanism; the third allocation mechanism is determined based on a method for allocating the capacity electricity fee between the new energy station and the power system, a method for allocating the capacity electricity fee between the photovoltaic station and the wind farm station of the new energy station, and the first allocation mechanism;

[0023] The fourth sharing module is used to determine the sharing result of the capacity cost of the pumped-storage power station on the user side based on the fourth sharing mechanism when the service scenario of the pumped-storage power station is the fourth scenario, based on the optimal solution; the fourth sharing mechanism is determined according to the sharing method of the capacity electricity fee between the new energy station and the power system, the sharing method of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station, and the second sharing mechanism.

[0024] In a third aspect, the present application provides a computer device comprising: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement any one of the above-described subject methods.

[0025] According to the specific embodiments provided in this application, this application has the following technical effects:

[0026] The present application provides a method, device and equipment for allocating the capacity cost of a pumped-storage power station on the user side, and adopts different allocation mechanisms to respectively determine the allocation results of the capacity cost of the pumped-storage power station on the user side when the pumped-storage power station serves a single regional power grid in the first scenario, serves multiple regional power grids in the second scenario, serves a new energy station and a single regional power grid in the third scenario, and serves a new energy station and multiple regional power grids in the fourth scenario. The allocation mechanism is determined according to the capacity electricity fee recovery mechanism, the profit sharing mechanism, the user equalization mechanism, the voltage level allocation mechanism, the allocation method between regional power grids, the allocation method between new energy stations and power systems, and the allocation method between photovoltaic stations and wind farms. The pumped-storage capacity electricity fee is allocated and channeled on the user side fairly and reasonably, which not only reduces the allocation pressure on the user side, but also effectively improves the cost recovery efficiency of the pumped-storage power station. BRIEF DESCRIPTION OF THE DRAWINGS

[0027] In order to more clearly illustrate the technical solutions in the embodiments of the present application or the prior art, the following will briefly introduce the drawings needed in the embodiments. Obviously, the drawings described below only illustrate some of the embodiments of the present application, and for those skilled in the art, other drawings can also be obtained from these drawings without creative labor.

[0028] Figure 1 An application environment diagram of a method for allocating pumped storage power station capacity cost on the user side according to an embodiment of the present application;

[0029] Figure 2 A flowchart of a method for allocating pumped storage power station capacity cost on the user side according to an embodiment of the present application;

[0030] Figure 3 A schematic diagram of an overall implementation process of a method for allocating pumped storage power station capacity cost on the user side in actual application according to an embodiment of the present application;

[0031] Figure 4 A schematic diagram of a refinement process of a scenario of the influence of a pumped storage capacity electricity cost allocation mechanism on user electricity prices in the prior art; Figure 3 A schematic diagram of a refinement process of a scenario of the influence of a pumped storage capacity electricity cost allocation mechanism on user electricity prices in the prior art;

[0032] Figure 5 A functional module schematic diagram of an allocation device for pumped storage power station capacity cost on the user side according to another embodiment of the present application;

[0033] Figure 6 A structural schematic diagram of a computer device according to an embodiment of the present application. DETAILED DESCRIPTION

[0034] The technical solutions in the embodiments of the present application will be described clearly and completely below with reference to the drawings in the embodiments of the present application. Obviously, the described embodiments are only some of the embodiments of the present application, rather than all the embodiments. Based on the embodiments in the present application, all other embodiments obtained by those skilled in the art without creative labor fall within the scope of the present application.

[0035] The above-mentioned purposes, features and advantages of the present application can be more obvious and easy to understand. The present application will be further described in detail below with reference to the drawings and specific embodiments.

[0036] The method for allocating pumped storage power station capacity cost on the user side provided by the embodiments of the present application can be applied to, for example, Figure 1The application environment is shown. Among them, the terminal 102 communicates with the server 104 through the network. The data storage system can store the data required by the server 104 to process. The data storage system can be separately arranged, or integrated on the server 104, or placed on the cloud or other servers. The terminal 102 can send the service scenario and the time sequence production simulation model of the pumped storage power station to the server 104. After receiving the service scenario and the time sequence production simulation model of the pumped storage power station, the server 104 solves the time sequence production simulation model for the service scenario and the time sequence production simulation model of the pumped storage power station, and obtains an optimal solution. When the service scenario of the pumped storage power station is the first scenario, based on the optimal solution, a first allocation mechanism is used to determine the allocation result of the pumped storage power station capacity cost on the user side. When the service scenario of the pumped storage power station is the second scenario, a second allocation mechanism is used to determine the allocation result of the pumped storage power station capacity cost on the user side. When the service scenario of the pumped storage power station is the third scenario, based on the optimal solution, a third allocation mechanism is used to determine the allocation result of the pumped storage power station capacity cost on the user side. When the service scenario of the pumped storage power station is the fourth scenario, based on the optimal solution, a fourth allocation mechanism is used to determine the allocation result of the pumped storage power station capacity cost on the user side.

[0037] The server 104 can feed back the obtained allocation result of the pumped storage power station capacity cost on the user side to the terminal 102. In addition, in some embodiments, the pumped storage power station capacity cost allocation method on the user side can also be realized by the server 104 or the terminal 102 alone, such as can be directly processed by the terminal 102 for the service scenario and the time sequence production simulation model of the pumped storage power station, or the server 104 can obtain the service scenario and the time sequence production simulation model of the pumped storage power station from the data storage system and process the service scenario and the time sequence production simulation model of the pumped storage power station.

[0038] Among them, the terminal 102 can be but not limited to various desktop computers, notebook computers, smart phones, tablet computers, Internet of Things devices and portable wearable devices. The Internet of Things device can be a smart speaker, a smart television, a smart air conditioner, a smart vehicle device, etc. The portable wearable device can be a smart watch, a smart bracelet, a head-mounted device, etc. The server 104 can be realized by an independent server or a server cluster composed of multiple servers, and can also be a cloud server.

[0039] In an exemplary embodiment, as Figure 2 shown, a pumped storage power station capacity cost allocation method on the user side is provided. The method is executed by a computer device, which can be executed by a terminal or a server alone, or by a terminal and a server together. In the embodiments of the present application, the method is applied to the application environment shown. Figure 1The server 104 in the example is used for explanation, including the following steps 201 to 207.

[0040] in:

[0041] Step 201 : determining the service scenarios of the pumped storage power station; the service scenarios include: a first scenario, a second scenario, a third scenario, and a fourth scenario.

[0042] Among them, the first scenario is that the pumped storage power station serves a single regional power grid; the second scenario is that the pumped storage power station serves multiple regional power grids; the third scenario is that the pumped storage power station serves a new energy station and a single regional power grid; the fourth scenario is that the pumped storage power station serves a new energy station and multiple regional power grids.

[0043] In practical applications, a provincial power grid can serve as a regional power grid, with new energy stations serving as specific power sources.

[0044] Step 202: construct a sequential production simulation model.

[0045] Among them, the time-series production simulation model includes: objective function and constraints; the objective function is constructed with the goal of maximizing the absorption capacity of the pumped storage power station for the new energy station; the constraints include: power balance constraints, system capacity constraints, system external power constraints, new energy station output constraints, thermal power unit output constraints, thermal power unit ramp rate constraints, hydropower unit output constraints, pumped storage unit output constraints and pumped storage power station storage capacity constraints.

[0046] Step 203 , solving the time-series production simulation model to obtain an optimal solution; the optimal solution includes: the output of the pumped-storage unit and the output of the new energy station when the pumped-storage power station has the maximum absorption capacity for the new energy station.

[0047] Step 204: When the service scenario of the pumped storage power station is the first scenario, based on the optimal solution, a first allocation mechanism is used to determine an allocation result of the capacity cost of the pumped storage power station on the user side.

[0048] Among them, the first sharing mechanism is determined according to the capacity electricity fee recovery mechanism, the profit sharing mechanism, the user equalization mechanism and the voltage level sharing mechanism.

[0049] Step 205: When the service scenario of the pumped storage power station is the second scenario, the second allocation mechanism is used to determine the allocation result of the capacity cost of the pumped storage power station on the user side.

[0050] Among them, the second sharing mechanism is determined based on the sharing method of capacity electricity charges among regional power grids, the user sharing mechanism and the voltage level sharing mechanism.

[0051] Step 206, when the service scenario of the pumped storage power station is the third scenario, based on the optimal solution, a third allocation mechanism is used to determine the allocation result of the capacity charge of the pumped storage power station on the user side.

[0052] The third allocation mechanism is determined according to the allocation manner of the capacity charge between the new energy station and the power system, the allocation manner of the capacity charge between the photovoltaic station and the wind power station of the new energy station, and the first allocation mechanism.

[0053] Step 207, when the service scenario of the pumped storage power station is the fourth scenario, based on the optimal solution, a fourth allocation mechanism is used to determine the allocation result of the capacity charge of the pumped storage power station on the user side.

[0054] The fourth allocation mechanism is determined according to the allocation manner of the capacity charge between the new energy station and the power system, the allocation manner of the capacity charge between the photovoltaic station and the wind power station of the new energy station, and the second allocation mechanism.

[0055] The implementation of the above steps 201 to 207 can fairly and reasonably allocate the pumped storage capacity charge on the user side, not only can reduce the allocation pressure on the user side, but also can effectively improve the recovery efficiency of the cost of the pumped storage power station.

[0056] In another exemplary embodiment of the present application, step 204 specifically includes:

[0057] (1) When the service scenario of the pumped storage power station is the first scenario, a capacity charge recovery mechanism is used to determine the capacity charge of the pumped storage power station borne by the regional power grid, or an output and benefit sharing mechanism of the pumped storage unit in the optimal solution is used to determine the capacity charge of the pumped storage power station borne by the regional power grid.

[0058] (2) According to the capacity charge of the pumped storage power station borne by the regional power grid, a user flat allocation mechanism or a voltage level allocation mechanism is used to determine the user price increase value in the regional power grid; the user price increase value in the regional power grid is used as the allocation result of the capacity charge of the pumped storage power station on the user side in the first scenario.

[0059] In another exemplary embodiment of the present application, step 205 specifically includes:

[0060] (1) When the service scenario of the pumped storage power station is the second scenario, an allocation manner of the capacity charge between regional power grids is used to determine the capacity charge of the pumped storage power station borne by each regional power grid in the plurality of regional power grids.

[0061] (2) According to the capacity charge of the pumped storage power station borne by the regional power grid, a user flat sharing mechanism or a voltage level sharing mechanism is used to determine the user price increase value in the regional power grid; the user price increase value in the regional power grid is used as the sharing result of the capacity charge of the pumped storage power station at the user side in the second scenario.

[0062] In another exemplary embodiment of the present application, step 206 specifically includes:

[0063] (1) When the service scenario of the pumped storage power station is the third scenario, the capacity charge of the pumped storage power station borne by the new energy station and the capacity charge of the pumped storage power station borne by the regional power grid are determined by using the capacity charge sharing mode between the new energy station and the power system.

[0064] (2) The capacity charge of the pumped storage power station borne by the photovoltaic station and the capacity charge of the pumped storage power station borne by the wind power station are determined by using the output of the new energy station, the capacity charge of the pumped storage power station borne by the new energy station, and the capacity charge sharing mode between the photovoltaic station and the wind power station of the new energy station in the optimal solution.

[0065] (3) According to the capacity charge of the pumped storage power station borne by the regional power grid, a user flat sharing mechanism or a voltage level sharing mechanism is used to determine the user price increase value in the regional power grid; the user price increase value in the regional power grid is used as the sharing result of the capacity charge of the pumped storage power station at the user side in the third scenario.

[0066] In another exemplary embodiment of the present application, step 207 specifically includes:

[0067] (1) When the service scenario of the pumped storage power station is the fourth scenario, the capacity charge of the pumped storage power station borne by the new energy station and the capacity charge of the pumped storage power station borne by all regional power grids are determined by using the capacity charge sharing mode between the new energy station and the power system.

[0068] (2) The capacity charge of the pumped storage power station borne by the photovoltaic station and the capacity charge of the pumped storage power station borne by the wind power station are determined by using the output of the new energy station, the capacity charge of the pumped storage power station borne by the new energy station, and the capacity charge sharing mode between the photovoltaic station and the wind power station of the new energy station in the optimal solution.

[0069] (3) According to the capacity charge of the pumped storage power station borne by all regional power grids, the capacity charge of the pumped storage power station borne by each regional power grid in the plurality of regional power grids is determined by using the capacity charge sharing mode between the regional power grids.

[0070] (4) For any regional power grid, the user flat-sharing mechanism or the voltage level sharing mechanism is used to determine the user price increase value in the regional power grid according to the capacity charge of the pumped storage power station corresponding to the corresponding user; the capacity charge of the pumped storage power station borne by the photovoltaic field station, the capacity charge of the pumped storage power station borne by the wind power field station and the user price increase value in each regional power grid are taken as the sharing result of the capacity charge of the pumped storage power station at the user side in the fourth scenario.

[0071] In another exemplary embodiment of the present application, the expression of the capacity charge recovery mechanism is:

[0072]

[0073] wherein, is the capacity charge of the pumped storage power station in the yth year; M is the number of pumped storage units in the pumped storage power station; P mgd is the installed capacity of the mth pumped storage unit; is the annual capacity price approved in the regulatory period in the yth year.

[0074] The expression of the benefit sharing mechanism is:

[0075]

[0076] wherein, p cgdm is the pumped storage price difference benefit of the pumped storage power station; Q mg is the power generation amount of the mth pumped storage unit; p mg is the annual average settlement price of the pumped storage unit running in the peak period; Q md is the pumped storage power generation amount of the mth pumped storage unit; p md is the annual average settlement price of the pumped storage unit running in the valley period; is the capacity charge of the pumped storage power station in the y+1th year; Q mg and Q md are determined according to the output of the pumped storage unit in the optimal solution.

[0077] The expression of the capacity charge sharing mode among regional power grids is:

[0078]

[0079] wherein, p nrgdm is the capacity charge of the pumped storage power station corresponding to the regional power grid n; is the capacity charge of the pumped storage power station PSC in a certain year in the second scenario; k n is the sharing ratio among regional power grids; N is the number of regional power grids.

[0080] The expression of the capacity charge sharing mode between the new energy field station and the power system is:

[0081] The expression of the capacity charge recovery mechanism is:

[0082] wherein p wvgdm is the capacity charge of the pumped storage power station borne by the new energy power station; p xtgdm is the capacity charge of the pumped storage power station borne by the regional power grid; k wv is the proportion of unit capacity allocated to the new energy power station; is the capacity charge of the pumped storage power station PSD in a certain year in the third scenario.

[0083] The expression of the user flat allocation mechanism is:

[0084]

[0085] wherein, is the value of the increase of user electricity price in the regional power grid n; is the annual electricity consumption of users in the regional power grid n; p nrgdm is the capacity charge of the pumped storage power station corresponding to the regional power grid n.

[0086] The expression of the allocation mechanism according to voltage level is:

[0087]

[0088] wherein, is the value of the increase of user electricity price in 1-10 (20) kV; is the value of the increase of user electricity price in 35-110 kV; is the value of the increase of user electricity price in 220 kV or above; is the allocation proportion of 1-10 (20) kV users; is the allocation proportion of 35-110 kV users; is the allocation proportion of 220 kV or above users; is the annual electricity consumption of 1-10 (20) kV users; is the annual electricity consumption of 35-110 kV users; is the annual electricity consumption of 220 kV or above users.

[0089] The allocation mode of capacity charge between photovoltaic power stations and wind power stations in the new energy power station is:

[0090]

[0091] wherein p wgdm is the capacity charge of the pumped storage power station borne by the wind power station; p vgdm is the capacity charge of the pumped storage power station borne by the photovoltaic power station; AQ w is the electricity quantity of the wind power station consumed by the pumped storage power station; AQ vis the photovoltaic power consumed by the pumped storage power station; ΔQ w and ΔQ v It is determined based on the output of the new energy station in the optimal solution (i.e. calculated through simulation methods).

[0092] In another exemplary embodiment of the present application, the sequential production simulation model in step 202 is introduced.

[0093] 1) Construct the objective function of the sequential production simulation model.

[0094] The absorption of new energy mainly depends on the peak load regulation capacity of the power system. That is, when the load is low, the excess new energy can be absorbed by reducing the output of conventional units or switching pumped storage units to pumping mode, etc., to reduce the wind and solar power curtailment rate. Therefore, with the goal of maximizing the absorption capacity of new energy stations, the objective function f is constructed as follows:

[0095]

[0096] Where, T is the scheduling time length; P w (t), P v (t) is the output of the wind farm and photovoltaic station at time t.

[0097] 2) Construct constraints for the sequential production simulation model.

[0098] (1) Power balance constraints:

[0099]

[0100] Among them, N is the number of thermal power units, P n (t,n) is the output of the nth thermal power unit at time t, H is the number of hydropower units, P h (t,h) is the output of the h-th hydropower unit at time t, P mg (t,m) is the power output of the mth pumped storage unit at time t, P md (t,m) is the pumping output of the mth pumped storage unit at time t, which takes a negative value. l (t) is the load power at time t, P s (t) is the system outgoing power at time t, and the incoming power is a negative value.

[0101] (2) System capacity constraints:

[0102] S P ≥P lmax ×(l1+l2)+P wv ×l3 (11)

[0103] Where S P is the spare capacity required by the system, Plmax To predict the maximum load, P wv To predict the output of new energy station, l1 is the load reserve percentage, l2 is the accident reserve percentage, and l3 is the predicted new energy output error reserve capacity demand percentage.

[0104] (3) System power delivery constraint:

[0105] P smin (t)≤P s (t)≤P smax (t) (12)

[0106] In the formula, P smax (t), P smin (t) is the upper and lower limit of the system power delivery planning at time t, that is, the maximum transmission capacity of the regional power system through the tie line to interact with the outside power, the value is positive to send electricity, belongs to the sending end power grid, otherwise belongs to the receiving end power grid.

[0107] (4) New energy unit output constraint:

[0108] 0≤P w (t)≤N w P * w (t) (13)

[0109] 0≤P v (t)≤N v P * v (t) (14)

[0110] In the formula, N w is the wind power installed capacity, P * w (t) is the normalized theoretical output of wind power at time t, N v is the photovoltaic installed capacity, P * v (t) is the normalized theoretical output of photovoltaic at time t.

[0111] (5) Thermal power unit output constraint:

[0112] P nmin (n)≤P n (t,n)≤P nmax (n) (15)

[0113] In the formula, P nmin (n) is the minimum technical output of the nth thermal power unit, P nmax (n) is the maximum technical output of the nth thermal power unit.

[0114] (6) Thermal power unit ramp rate constraint:

[0115] P n (t+1,n)-P n (t,n)≤P nup (n) (16)

[0116] P n (t,n)-P n (t+1,n)≤P ndown (n) (17)

[0117] Where, P nup (n) is the ramp rate of the nth thermal power unit, P ndown (n) is the ramp rate of the nth thermal power plant, P n (t+1,n) is the output of the nth thermal power unit at time t+1.

[0118] (7) Output constraints of hydropower units:

[0119] P hmin (h)≤P h (t,h)≤P hmax (h) (18)

[0120] Where, P hmin (h) is the minimum technical output of the h-th hydropower unit, P hmax (h) is the maximum technical output of the h-th hydropower unit.

[0121] (8) Output constraints of pumped storage units:

[0122] P mg (t,m)×P md (t,m)=0 (19)

[0123] P mgmin (m)≤P mg (t,m)≤P mgmax (m) (20)

[0124] P mdmin (m)≤P md (t,m)≤P mdmax (m) (21)

[0125] Where, P mgmin (m) is the minimum output of the mth pumped storage unit under power generation conditions, P mgmax (m) is the maximum output of the mth pumped storage unit under power generation conditions, P mdmin (m) is the minimum output of the mth pumped storage unit under pumping conditions, P mdmax (m) is the maximum output of the mth pumped storage unit under pumping conditions.

[0126] (9) Pumped storage power station reservoir capacity constraint:

[0127] Q su ≤(Q smg -Q smd )≤Q sd (22)

[0128] In the formula, Q su is the upper reservoir regulating capacity, Q smg is the water consumption in power generation condition, Q smd is the water consumption in pumping condition, and Q sd is the lower reservoir regulating capacity.

[0129] According to the relationship between the regulating capacity and the pumping and power generation capacity, the pumped storage power station reservoir capacity constraint can be converted into the following constraint:

[0130]

[0131] In the formula, T mmax is the maximum full-load hours of the mth unit in the dispatching period, T D is the simulation step, and λ mgd is the pumping and power conversion efficiency.

[0132] For the cyclic unit with day or week as the unit, the upper reservoir water level at the start and end period should be kept consistent, that is:

[0133]

[0134] The following will be combined with Figure 3 and Figure 4 to introduce an implementation process of the user-side sharing method of the pumped storage power station capacity cost in actual application, taking the provincial power grid as an example.

[0135] S1: Sort out the existing pumped storage capacity electricity cost allocation mechanism. According to relevant documents, the capacity price of pumped storage power station in a certain regulatory period is determined according to the pricing method during the operation period, and the capacity electricity cost of the power station in each year of the initial regulatory period is equal to the capacity price multiplied by the installed capacity. If the pumped storage power station participates in the power auxiliary service market and obtains income through arbitrage of pumping and generating price difference in the initial regulatory period, 20% of these income will be shared by the pumped storage power station in the next regulatory period, and will be deducted when the capacity price is determined. If there is no income, but loss, the pumped storage power station will bear it, and the capacity price will be the same as the initial regulatory period. For a pumped storage power station, if it serves multiple provincial power grids, the capacity electricity cost will be allocated among the provincial power grids in a certain proportion; if it serves new energy stations and power systems, the capacity electricity cost will also be allocated between the two in a certain proportion. The part of capacity electricity cost borne by the grid or power system will be allocated to the industrial and commercial users in its region. Specifically:

[0136] (1) Sort out the capacity electricity cost recovery mechanism.

[0137] The relevant opinions point out that the capacity electricity cost corresponding to the determined capacity price of pumped storage is paid by the grid enterprise and included in the provincial grid transmission and distribution price recovery. Another relevant opinion determines the capacity price of 48 power stations in operation and to be put into operation by the end of 2025. The capacity electricity cost of pumped storage power station in the yth year is shown in formula (1), which will not be repeated here.

[0138] (2) Sort out the relevant benefit sharing mechanism.

[0139] The relevant opinions point out that 20% of the auxiliary service income and arbitrage income of the power station in the last regulatory period will be shared by the pumped storage power station, and 80% will be deducted when the capacity price of the power station is determined in the next regulatory period, and the loss will be borne by the pumped storage power station. In order to highlight the role of pumped storage in new energy consumption, it is assumed that 100% of the capacity of pumped storage power station participates in system peak shaving and arbitrage in the spot market through pumping and generating price difference. The annual average pumping and generating price difference income of pumped storage power station is shown in formula (2), which will not be repeated here.

[0140] Since the relevant opinions do not give the deduction rules of pumping and generating price difference income, the price difference income of this year will be included in the capacity electricity cost of the power station next year, and the capacity electricity cost of pumped storage power station in the y+1th year is shown in formula (3), which will not be repeated here.

[0141] (3) Clarify the allocation method of capacity electricity cost in regional power grid.

[0142] The “Pumped Storage Price Mechanism Opinion” proposes to clearly allocate the capacity charge among regions according to the function and service of pumped storage. If the pumped storage power station PSC serves N provincial grids, the capacity charge borne by each provincial grid is shown in formula (4), which is not described in detail here.

[0143] (4) Clearly allocate the capacity charge among specific power sources and power systems.

[0144] The relevant opinion proposes that the project clearly allocates the capacity charge among specific power sources and power systems according to the approved documents. Assuming that the specific power source is a large wind and solar base, if the pumped storage power station PSD (pumped storage power station in the third scenario) serves the new energy station and the power system, the capacity charge borne by the two is shown in formula (5), which is not described in detail here.

[0145] S2: Design scenarios for the impact of pumped storage capacity charge on user electricity prices. The allocation of pumped storage capacity charge to the user side can be divided into the following four scenarios. Scenario 1 (i.e., the first scenario): The pumped storage power station PSA serves a single provincial grid, and the capacity charge of the power station is borne entirely by the provincial users. Scenario 2 (i.e., the second scenario): The pumped storage power station PSC serves multiple provincial grids, and the capacity charge is first allocated among the provincial grids according to the inter-provincial proportion, and then transmitted to the provincial users. Scenario 3 (i.e., the third scenario): The pumped storage power station PSD serves a specific power source and a single provincial grid, and the capacity charge is first allocated between the power source and the provincial grid according to the capacity proportion, and then transmitted to the power source side and the user side, respectively. Scenario 4 (i.e., the fourth scenario): The pumped storage power station PSE serves a specific power source and multiple provincial grids, and the capacity charge is first allocated between the power source and the multiple provincial grids according to the capacity proportion, and then the part borne by the provincial grids is allocated among the provincial grids according to the inter-provincial proportion, and finally transmitted to the provincial user side. Specifically:

[0146] (1) Design scenarios for the allocation of all pumped storage capacity charges to users (Scenario 1 and Scenario 3).

[0147] At present, the industrial and commercial user electricity price is composed of five parts: the on-grid electricity price, the on-grid link loss cost, the transmission and distribution price, the system operation cost and fund, and the additional cost. The pumped storage capacity charge is calculated on a provincial basis and is included in the user system operation cost separately from the transmission and distribution price. If it is allocated evenly among all users, the increase in the provincial grid n user electricity price is shown in formula (6), which is not described in detail here.

[0148] At present, the transmission and distribution cost is allocated among users at different electricity price levels, which is specifically reflected in the different transmission and distribution prices of users at different voltage levels. The higher the voltage level, the lower the transmission and distribution price, and the less the allocated cost, and vice versa. Referring to the allocation of the transmission and distribution cost, the pumped storage capacity electricity fee is not fair to users at high voltage levels, so the present application divides users into three gears according to the voltage level, and sets different allocation coefficients for each gear. The user price increase value is shown in formula (7), which will not be described in detail here.

[0149] (2) Design the scenario of allocating part of the pumped storage capacity electricity fee to users (Scenario 2 and Scenario 4).

[0150] In this case, the pumped storage capacity electricity fee is first allocated between the new energy station and the power system according to the capacity proportion, and the part borne by the power system is then conducted to the user side. The user price increase value can be calculated by formula (6) or formula (7), which will not be described in detail here. The part borne by the new energy can be allocated between wind power and photovoltaic according to the different degrees of consumption of pumped storage. Through the power system simulation method, the increase value of wind power and photovoltaic power generation before and after the pumped storage power station is integrated into the power system is measured to quantify the different degrees of consumption of pumped storage to the two, and then the allocation proportion of the capacity electricity fee between the two is set. The capacity electricity fee that should be allocated by wind power and photovoltaic is shown in formula (8), which will not be described in detail here.

[0151] S3: Construct an allocation model based on the time sequence production simulation method (i.e. time sequence production simulation simulation model). For the time sequence production model, the result obtained by solving with MATLAB software in cooperation with CPLEX is brought into the allocation scenario designed in S2, and then the allocation results under the four allocation scenarios are obtained.

[0152] The above embodiments are to improve the fairness and rationality of the allocation of the capacity electricity fee at the user side. The allocation model of the pumped storage capacity electricity fee at the user side based on the time sequence production simulation method realizes the allocation of the capacity electricity fee at the user side. First, the pumped storage power station capacity electricity fee allocation and dredging mechanism at the present stage is sorted out, then the allocation scenario at the user side is designed, and finally the allocation results of the capacity electricity fee under various scenarios are calculated by the time sequence production simulation method. The method mentioned can allocate the pumped storage capacity electricity fee at the user side fairly and reasonably, not only can reduce the allocation pressure at the user side, but also can effectively improve the recovery efficiency of the cost and fee of the pumped storage power station.

[0153] The influence of pumped storage capacity electricity cost allocation mechanism on user electricity price is quantified, and it is found that the installed capacity of pumped storage power station, capacity price, income level, cost allocation method and user side allocation standard all have an impact on user electricity price. Due to the large proportion of capacity cost in the total cost of pumped storage power station, with the large-scale development of pumped storage power station, perfect pricing mechanism and fair and reasonable cost allocation method can not only reduce the burden of user side electricity price, but also help to improve the cost recovery efficiency of pumped storage power station. The simulation results show that:

[0154] (1) At present, the income of pumped storage power station is affected by factors such as limited arbitrage space of pumped storage power station in spot market, imperfect auxiliary service market mechanism, etc., and the overall income is low, and some power stations may even incur losses. With the development of electricity market, the income space will increase, and the capacity price will further decrease. It is suggested that in the next stage, according to the actual operation of the power station, the "capacity price unit + market unit" profit mode should be adopted, that is, the power station leaves part of the unit to undertake the "guaranteed" task, and the remaining capacity participates in the market, so as to improve the overall economic benefit of pumped storage power station, reduce the recovery of capacity electricity cost, and further increase the recovery efficiency of pumped storage power station cost.

[0155] (2) According to the simulation results, the pumped storage capacity electricity cost allocation method can be improved from the following three aspects. First, for the provinces with close grid structure, "shared pumped storage power station" can be considered, and the allocation proportion can be negotiated by the provincial grid companies, which can optimize the regional resource allocation and reduce the user electricity price by expanding the allocation range. Second, for the provinces with concentrated pumped storage resources, a certain scale of new energy station can be considered to undertake part of the capacity electricity cost to reduce the cost of the user side, so as to realize the win-win situation of "increasing new energy consumption and reducing user electricity price increase". Third, for the areas with geological conditions, the pumped storage power station can be reserved to improve the self-adjusting ability of the integrated large base project. The pumped storage capacity electricity cost can be digested within the project or the wind and light storage base can be considered as a whole to determine the comprehensive on-grid price, and the capacity electricity cost will not be transmitted to the user side, further reducing the pressure on user electricity price.

[0156] (3) According to the simulation results, it is suggested that two-level allocation index system can be considered for the user side. The first level classifies the user side according to voltage level, and the higher the voltage level, the less the use of transmission and distribution resources, and the smaller the allocation weight. The second level divides the users with the same voltage level into 2-5 grades according to the fluctuation of user load in a certain period of time. The more intense the load fluctuation, the higher the use of system regulation resources, and the larger the allocation weight. Through the two-level allocation index system, the user side can be classified in detail to ensure the fair and reasonable allocation of pumped storage capacity electricity cost among users.

[0157] Based on the same inventive concept, the application further provides a user-side pumped storage power station capacity cost allocation device for implementing the user-side pumped storage power station capacity cost allocation method described above. The solution provided by the device is similar to the solution described in the method, so the specific limitations in one or more embodiments of the user-side pumped storage power station capacity cost allocation device provided below can refer to the limitations of the user-side pumped storage power station capacity cost allocation method described above, which will not be repeated here.

[0158] In one exemplary embodiment, as shown in Figure 5 a user-side pumped storage power station capacity cost allocation device is provided, comprising:

[0159] A service scenario determination module 301 is configured to determine a service scenario of the pumped storage power station; the service scenario includes a first scenario, a second scenario, a third scenario, and a fourth scenario; the first scenario is that the pumped storage power station serves a single regional power grid; the second scenario is that the pumped storage power station serves multiple regional power grids; the third scenario is that the pumped storage power station serves a new energy station and a single regional power grid; and the fourth scenario is that the pumped storage power station serves a new energy station and multiple regional power grids.

[0160] A simulation model construction module 302 is configured to construct a time-series production simulation model; the time-series production simulation model includes an objective function and a constraint condition; the objective function is constructed with the maximum consumption of the new energy station by the pumped storage power station as the target; and the constraint condition includes power balance constraints, system capacity constraints, system external power constraints, new energy station output constraints, thermal power unit output constraints, thermal power unit ramping rate constraints, hydropower unit output constraints, pumped storage unit output constraints, and pumped storage power station storage capacity constraints.

[0161] A solution module 303 is configured to solve the time-series production simulation model to obtain an optimal solution; the optimal solution includes the output of the pumped storage unit and the output of the new energy station when the consumption of the new energy station by the pumped storage power station is maximum.

[0162] A first allocation module 304 is configured to, when the service scenario of the pumped storage power station is the first scenario, determine a user-side pumped storage power station capacity cost allocation result based on the optimal solution by using a first allocation mechanism; and the first allocation mechanism is determined according to a capacity electricity cost recovery mechanism, a revenue sharing mechanism, a user flat allocation mechanism, and a voltage level allocation mechanism.

[0163] The second allocation module 305 is configured to determine the allocation result of the capacity cost of the pumped storage power station on the user side by using a second allocation mechanism when the service scenario of the pumped storage power station is the second scenario; and the second allocation mechanism is determined according to the allocation manner of the capacity electricity fee between regional power grids, the user flat allocation mechanism and the voltage level allocation mechanism.

[0164] The third allocation module 306 is configured to determine the allocation result of the capacity cost of the pumped storage power station on the user side by using a third allocation mechanism based on the optimal solution when the service scenario of the pumped storage power station is the third scenario; and the third allocation mechanism is determined according to the allocation manner of the capacity electricity fee between the new energy station and the power system, the allocation manner of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station and the first allocation mechanism.

[0165] The fourth allocation module 307 is configured to determine the allocation result of the capacity cost of the pumped storage power station on the user side by using a fourth allocation mechanism based on the optimal solution when the service scenario of the pumped storage power station is the fourth scenario; and the fourth allocation mechanism is determined according to the allocation manner of the capacity electricity fee between the new energy station and the power system, the allocation manner of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station and the second allocation mechanism.

[0166] In an exemplary embodiment, a computer device can be provided, which can be a server or a terminal, and an internal structure diagram thereof can be as shown in Figure 6 The computer device includes a processor, a memory, an input / output interface (I / O) and a communication interface. The processor, the memory and the input / output interface are connected through a system bus, and the communication interface is connected to the system bus through the input / output interface. The processor of the computer device is configured to provide computing and control capabilities. The memory of the computer device includes a non-volatile storage medium and an internal memory. The non-volatile storage medium stores an operating system, a computer program and a database. The internal memory provides an environment for the operation of the operating system and the computer program in the non-volatile storage medium. The database of the computer device is configured to store the service scenario of the pumped storage power station and the time sequence production simulation model. The input / output interface of the computer device is configured to exchange information between the processor and external devices. The communication interface of the computer device is configured to communicate with external terminals through network connection. The computer program is executed by the processor to implement a method for allocating the capacity cost of the pumped storage power station on the user side.

[0167] Those skilled in the art can understand that Figure 6The structure shown in the figure is only a block diagram of part of the structure related to the scheme of the present application, and does not constitute a limitation on the computer device to which the scheme of the present application is applied. The specific computer device can include more or fewer components than those shown in the figure, or combine certain components, or have a different arrangement of components.

[0168] In an exemplary embodiment, a computer device is also provided, including a memory and a processor, the memory storing a computer program, and the processor implementing the steps in the above method embodiments when executing the computer program.

[0169] In an exemplary embodiment, a computer readable storage medium is provided, storing a computer program, and the computer program implements the steps in the above method embodiments when executed by a processor.

[0170] In an exemplary embodiment, a computer program product is provided, including a computer program, and the computer program implements the steps in the above method embodiments when executed by a processor.

[0171] A person of ordinary skill in the art can understand that all or part of the processes in the above method embodiments can be completed by a computer program instructing related hardware. The computer program can be stored in a non-volatile computer readable storage medium and can include the processes of the above method embodiments when executed. Any reference to a memory, database, or other medium used in the embodiments provided by the present application can include at least one of a non-volatile and volatile memory. The non-volatile memory can include a read-only memory (ROM), a magnetic tape, a floppy disk, a flash memory, an optical storage, a high-density embedded non-volatile memory, a resistive memory (ReRAM), a magnetoresistive random access memory (MRAM), a ferroelectric memory (FRAM), a phase change memory (PCM), a graphene memory, etc. The volatile memory can include a random access memory (RAM) or an external cache memory, etc. As an illustration but not as a limitation, the RAM can be in various forms, such as a static random access memory (SRAM) or a dynamic random access memory (DRAM), etc.

[0172] The database involved in each of the embodiments provided in the present application can include at least one of a relational database and a non-relational database. The non-relational database can include a distributed database based on a blockchain, and the like, without being limited thereto. The processor involved in each of the embodiments provided in the present application can be a general-purpose processor, a central processing unit, a graphics processing unit, a digital signal processor, a programmable logic device, and the like, without being limited thereto.

[0173] The technical features of the above embodiments can be combined in any manner. To make the description concise, all possible combinations of the technical features in the above embodiments are not described, but as long as the combinations of the technical features do not exist in contradiction, they shall be considered within the scope of the present application.

[0174] The principles and implementation manners of the present application are described by applying specific examples herein, and the above embodiments are only used to help understand the method of the present application and its core idea. Meanwhile, for those skilled in the art, the specific implementation manners and application ranges will be changed according to the idea of the present application. In conclusion, the content of the present application should not be understood as a limitation.

Claims

1. A method for allocating capacity costs of a pumped storage power station on the user side, characterized in that: The method for allocating the capacity cost of the pumped storage power station on the user side includes: Determine service scenarios for the pumped storage power station; the service scenarios include: a first scenario, a second scenario, a third scenario, and a fourth scenario; the first scenario is that the pumped storage power station serves a single regional power grid; the second scenario is that the pumped storage power station serves multiple regional power grids; the third scenario is that the pumped storage power station serves a new energy station and a single regional power grid; the fourth scenario is that the pumped storage power station serves a new energy station and multiple regional power grids; Constructing a time-series production simulation model; the time-series production simulation model includes: an objective function and constraints; the objective function is constructed with the goal of maximizing the absorption capacity of the pumped-storage power station for the new energy station; the constraints include: power balance constraints, system capacity constraints, system external power constraints, new energy station output constraints, thermal power unit output constraints, thermal power unit ramp rate constraints, hydropower unit output constraints, pumped-storage unit output constraints, and pumped-storage power station storage capacity constraints; Solving the time-series production simulation model to obtain an optimal solution; the optimal solution includes: the output of the pumped-storage unit and the output of the new energy station when the pumped-storage power station has the maximum capacity to absorb the new energy station; When the service scenario of the pumped storage power station is the first scenario, based on the optimal solution, a first allocation mechanism is adopted to determine the allocation result of the capacity cost of the pumped storage power station on the user side; the first allocation mechanism is determined according to a capacity electricity fee recovery mechanism, a revenue sharing mechanism, a user equalization mechanism, and an allocation mechanism based on voltage level; When the service scenario of the pumped storage power station is the second scenario, a second allocation mechanism is used to determine the allocation result of the capacity fee of the pumped storage power station on the user side; the second allocation mechanism is determined based on the allocation method of the capacity electricity fee among the regional power grid, the user equalization mechanism, and the allocation mechanism based on voltage level; When the service scenario of the pumped storage power station is the third scenario, based on the optimal solution, a third sharing mechanism is adopted to determine the user-side sharing result of the capacity fee of the pumped storage power station; the third sharing mechanism is determined according to the sharing method of the capacity electricity fee between the new energy station and the power system, the sharing method of the capacity electricity fee between the photovoltaic station and the wind farm station of the new energy station, and the first sharing mechanism; When the service scenario of the pumped-storage power station is the fourth scenario, based on the optimal solution, the fourth sharing mechanism is adopted to determine the sharing result of the capacity cost of the pumped-storage power station on the user side; the fourth sharing mechanism is determined according to the sharing method of the capacity electricity fee between the new energy station and the power system, the sharing method of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station, and the second sharing mechanism.

2. The method for allocating capacity costs of a pumped storage power station on the user side according to claim 1, characterized in that: When the service scenario of the pumped storage power station is the first scenario, based on the optimal solution, a first allocation mechanism is used to determine the allocation result of the capacity cost of the pumped storage power station on the user side, specifically including: When the service scenario of the pumped storage power station is the first scenario, the capacity electricity fee recovery mechanism is adopted to determine the capacity electricity fee of the pumped storage power station borne by the regional power grid, or the output and revenue sharing mechanism of the pumped storage unit in the optimal solution is adopted to determine the capacity electricity fee of the pumped storage power station borne by the regional power grid; Based on the capacity electricity charges of the pumped-storage power station borne by the regional power grid, the user equalization mechanism or the voltage level sharing mechanism is adopted to determine the increase in electricity prices for users in the regional power grid; the increase in electricity prices for users in the regional power grid serves as the result of the sharing of the capacity costs of the pumped-storage power station on the user side in the first scenario.

3. The method for allocating capacity costs of a pumped storage power station on the user side according to claim 2, characterized in that: The expression of the capacity electricity fee recovery mechanism is: in, is the capacity electricity fee of the pumped storage power station in the yth year; M is the number of pumped storage units in the pumped storage power station; P mgd is the installed capacity of the mth pumped storage unit; The annual capacity electricity price approved in the regulatory cycle of year y; The revenue sharing mechanism is expressed as: Among them, p cgdm is the price difference income of the pumped storage power station; Q mg is the power generated by the mth pumped storage unit; p mg is the annual average settlement price of the pumped storage unit during peak hours; Q md is the pumped power of the mth pumped storage unit; p md The annual average settlement price of the pumped storage unit during off-peak hours; is the capacity electricity fee of the pumped storage power station in year y+1; Q mg and Q md It is determined based on the output of the pumped storage unit in the optimal solution; The expression of the user amortization mechanism is: in, is the increase in electricity price for users in regional power grid n; is the annual electricity consumption of users in regional power grid n; p nrgdm is the capacity electricity fee of the pumped storage power station corresponding to the regional grid n; The expression of the voltage level allocation mechanism is: in, The increase in electricity prices for users of 1-20 kV; The electricity price increase for users of 35-110 kV; The increase in electricity price for users with voltage greater than or equal to 220 kV; The apportionment ratio for users of 1 to 20 kV; The apportionment ratio for users of 35-110 kV; The apportionment ratio for users with voltage greater than or equal to 220 kV; Annual electricity consumption of 1-20 kV users; The annual electricity consumption of 35-110 kV users; The annual electricity consumption of users greater than or equal to 220 kV.

4. The method for allocating capacity costs of a pumped storage power station on the user side according to claim 1, characterized in that: When the service scenario of the pumped storage power station is the second scenario, the second allocation mechanism is used to determine the allocation result of the capacity cost of the pumped storage power station on the user side, specifically including: When the service scenario of the pumped storage power station is the second scenario, the capacity electricity fee of the pumped storage power station borne by each of the multiple regional power grids is determined by adopting a method of allocating the capacity electricity fee among the regional power grids; For any regional power grid, the increase in electricity prices for users in the regional power grid is determined by adopting a user-sharing mechanism or a voltage-level sharing mechanism based on the capacity electricity charges of the corresponding pumped-storage power station. The increase in electricity prices for users in each regional power grid serves as the result of sharing the capacity costs of the pumped-storage power station on the user side in the second scenario.

5. The method for allocating capacity costs of a pumped storage power station on the user side according to claim 4, characterized in that: The expression for allocating capacity electricity charges among regional power grids is: Among them, p nrgdm is the capacity electricity fee of the pumped storage power station corresponding to the regional grid n; is the capacity electricity fee of the pumped storage power station in a certain year in the second scenario; k n is the sharing ratio among regional power grids; N is the number of regional power grids.

6. The method for allocating capacity costs of a pumped storage power station on the user side according to claim 1, characterized in that: When the service scenario of the pumped storage power station is the third scenario, based on the optimal solution, the third allocation mechanism is adopted to determine the allocation result of the capacity cost of the pumped storage power station on the user side, specifically including: When the service scenario of the pumped storage power station is the third scenario, the capacity electricity fee of the pumped storage power station borne by the new energy station and the capacity electricity fee of the pumped storage power station borne by the regional power grid are determined by adopting the method of allocating the capacity electricity fee between the new energy station and the power system; Determine the capacity electricity fee of the pumped storage power station borne by the photovoltaic station and the capacity electricity fee of the pumped storage power station borne by the wind power station by using the output of the new energy station in the optimal solution, the capacity electricity fee of the pumped storage power station borne by the new energy station, and the allocation method of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station; Based on the capacity electricity charge of the pumped-storage power station borne by the regional power grid, the user equalization mechanism or the voltage level sharing mechanism is adopted to determine the increase in electricity prices for users in the regional power grid; the capacity electricity charge of the pumped-storage power station borne by the photovoltaic station, the capacity electricity charge of the pumped-storage power station borne by the wind farm, and the increase in electricity prices for users in the regional power grid are used as the results of the sharing of the capacity cost of the pumped-storage power station on the user side in the third scenario.

7. The method for allocating capacity costs of a pumped storage power station on the user side according to claim 6, characterized in that: The expression for the allocation of capacity electricity charges between new energy stations and the power system is: Among them, p wvgdm Capacity electricity charges of pumped storage power stations borne by new energy stations; xtgdm Capacity electricity charges of pumped storage power stations borne by the regional power grid; k wv The proportion of unit capacity allocated to new energy stations; is the capacity electricity fee of the pumped storage power station in a certain year in the third scenario; The capacity electricity fee is allocated between the photovoltaic and wind power stations in the new energy stations as follows: Among them, p wgdm The capacity electricity fee of the pumped storage power station borne by the wind farm station; vgdm The capacity electricity fee of the pumped storage power station borne by the photovoltaic station; ΔQ w is the wind farm electricity consumed by the pumped storage power station; ΔQ v is the photovoltaic power consumed by the pumped storage power station; ΔQ w and ΔQ v It is determined based on the output of the new energy station in the optimal solution.

8. The method for allocating capacity costs of a pumped storage power station on the user side according to claim 1, characterized in that: When the service scenario of the pumped storage power station is the fourth scenario, based on the optimal solution, the fourth allocation mechanism is adopted to determine the allocation result of the capacity cost of the pumped storage power station on the user side, specifically including: When the service scenario of the pumped storage power station is the fourth scenario, the capacity electricity fee of the pumped storage power station borne by the new energy station and the capacity electricity fee of the pumped storage power station borne by all regional power grids is determined by adopting the method of allocating the capacity electricity fee between the new energy station and the power system; Determine the capacity electricity fee of the pumped storage power station borne by the photovoltaic station and the capacity electricity fee of the pumped storage power station borne by the wind power station by using the output of the new energy station in the optimal solution, the capacity electricity fee of the pumped storage power station borne by the new energy station, and the allocation method of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station; Based on the capacity electricity charges of the pumped storage power stations borne by all regional power grids, the capacity electricity charges of the pumped storage power stations borne by each of the multiple regional power grids are determined by adopting a method of allocating the capacity electricity charges among the regional power grids; For any regional power grid, the increase in electricity prices for users in the regional power grid is determined by adopting a user equalization mechanism or a voltage level sharing mechanism based on the capacity electricity charges of the corresponding pumped-storage power stations. The capacity electricity charges of the pumped-storage power stations borne by photovoltaic stations, the capacity electricity charges of the pumped-storage power stations borne by wind farms, and the increase in electricity prices for users in each regional power grid serve as the results of the sharing of the capacity costs of the pumped-storage power stations on the user side in the fourth scenario.

9. A device for allocating capacity costs of a pumped storage power station on the user side, characterized in that: The device for allocating the capacity cost of the pumped storage power station on the user side includes: A service scenario determination module is used to determine the service scenarios of the pumped storage power station; the service scenarios include: a first scenario, a second scenario, a third scenario, and a fourth scenario; the first scenario is that the pumped storage power station serves a single regional power grid; the second scenario is that the pumped storage power station serves multiple regional power grids; the third scenario is that the pumped storage power station serves a new energy station and a single regional power grid; the fourth scenario is that the pumped storage power station serves a new energy station and multiple regional power grids; A simulation model construction module is used to construct a time-series production simulation model; the time-series production simulation model includes: an objective function and constraints; the objective function is constructed with the goal of maximizing the absorption capacity of the pumped storage power station for the new energy station; the constraints include: power balance constraints, system capacity constraints, system external power constraints, new energy station output constraints, thermal power unit output constraints, thermal power unit ramp rate constraints, hydropower unit output constraints, pumped storage unit output constraints, and pumped storage power station storage capacity constraints; A solution module is used to solve the time-series production simulation model to obtain an optimal solution; the optimal solution includes: the output of the pumped-storage unit and the output of the new energy station when the pumped-storage power station has the maximum absorption capacity for the new energy station; A first allocation module is configured to, when the service scenario of the pumped-storage power station is the first scenario, determine, based on the optimal solution, an allocation result of the capacity cost of the pumped-storage power station on the user side using a first allocation mechanism; the first allocation mechanism is determined based on a capacity electricity fee recovery mechanism, a revenue sharing mechanism, a user equalization mechanism, and an allocation mechanism based on voltage level; A second allocation module is configured to, when the service scenario of the pumped-storage power station is the second scenario, determine the allocation result of the capacity cost of the pumped-storage power station on the user side using a second allocation mechanism; the second allocation mechanism is determined based on the allocation method of the capacity electricity fee among regional power grids, the user equalization mechanism, and the voltage level allocation mechanism; A third allocation module is configured to, when the service scenario of the pumped-storage power station is the third scenario, determine, based on the optimal solution, a result of allocating the capacity fee of the pumped-storage power station on the user side using a third allocation mechanism; the third allocation mechanism is determined based on a method for allocating the capacity electricity fee between the new energy station and the power system, a method for allocating the capacity electricity fee between the photovoltaic station and the wind farm station of the new energy station, and the first allocation mechanism; The fourth sharing module is used to determine the sharing result of the capacity cost of the pumped-storage power station on the user side based on the fourth sharing mechanism when the service scenario of the pumped-storage power station is the fourth scenario, based on the optimal solution; the fourth sharing mechanism is determined according to the sharing method of the capacity electricity fee between the new energy station and the power system, the sharing method of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station, and the second sharing mechanism.

10. A computer device comprising: A memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that the processor executes the computer program to implement the method for allocating the capacity cost of a pumped storage power station on the user side according to any one of claims 1 to 8.

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