Method, device and equipment for sharing capacity cost of pumped storage power station at user side

Abstract

The invention discloses a method, a device and equipment for sharing the capacity cost of a pumped storage power station at a user side, and relates to the field of capacity cost sharing, and the method comprises the steps: solving a time sequence production simulation model, and obtaining an optimal solution; based on an optimal solution; a first scene serving a single regional power grid, a second scene serving a plurality of regional power grids and a third scene serving a new energy station and the single regional power grid of the pumped storage power station are respectively determined by adopting different allocation mechanisms; the allocation result of the capacity cost of the power station at the user side is pumped and stored in a fourth scene serving the new energy station and the plurality of regional power grids; the allocation mechanism is determined according to a capacity electricity charge recovery mechanism, an income sharing mechanism, a user sharing mechanism, a voltage grade allocation mechanism, an allocation mode between 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. According to the invention, the pumped storage capacity electric charge can be shared and dredged fairly and reasonably at the user side.

Description

Technical Field

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

[0002] In recent years, new energy sources have been continuously connected to the power system on a large scale and at a high proportion, which has put forward higher requirements for the system's flexible adjustment capabilities. Pumped storage is currently the most mature energy storage technology. As the main means to improve the flexibility of the power system, it has received widespread attention and ushered in explosive growth. Since the construction cost of pumped storage power stations (referred to as pumped storage power stations) accounts for a large proportion of the total cost, with the large-scale construction of power stations, huge capacity electricity charges will also be generated.

[0003] At present, the capacity electricity fee of pumped-storage power stations is determined by the operating period pricing method, which not only ensures that the capacity cost of the power station can be fully recovered, but also gives the power station an annual internal rate of return of 6.5% by benchmarking against advanced industries. The current mechanism can already well guarantee the recovery of the capacity cost of pumped-storage power stations, but the corresponding capacity electricity fee will eventually be transmitted to the user side, causing the electricity price of industrial and commercial users to rise, leading to complaints from some users, which will in turn affect the recovery efficiency of the capacity cost of pumped-storage power stations. The imperfect method of allocating capacity electricity fees on the user side has become the main factor restricting the large-scale development of pumped-storage power stations.

[0004] At present, there are few studies on the allocation and guidance methods of capacity electricity charges for pumped-storage power stations. Most of them focus on the following two aspects: first, determine the allocation ratio of capacity electricity charges of pumped-storage power stations in multiple regional power grids (such as provincial power grids) according to the functions and service conditions of pumped-storage power stations; second, clarify the allocation ratio of capacity electricity charges of pumped-storage power stations between new energy sites and power systems according to relevant standards. Regardless of the proportion of capacity electricity charges of pumped-storage power stations among multiple regional power grids and between new energy sites and power grids, the part borne by the power grid side will eventually be transmitted to the industrial and commercial user side in the region. If there is no relatively complete allocation method on the user side, it will eventually lead to low cost recovery efficiency of the power station, thereby affecting the investment confidence of social capital and hindering the construction and development of pumped-storage power stations to a certain extent.

[0005] With the gradual commissioning of pumped-storage power stations, pumped-storage power stations 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 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;

[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 of new energy stations by the pumped-storage power 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 largest consumption of 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 the capacity electricity fee recovery mechanism, the revenue sharing mechanism, the user equalization mechanism and the voltage level allocation mechanism;

[0013] 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; the second allocation mechanism is determined according to the allocation method of the capacity electricity fee among the regional power grids, the user equalization mechanism and the allocation mechanism according to the 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 adopted to determine the allocation result of the capacity fee of the pumped storage power station on the user side; the third allocation mechanism is determined according to the allocation method of the capacity electricity fee between the new energy station and the power system, the allocation method of the capacity electricity fee between the photovoltaic station and the wind farm 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, 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 capacity electricity charges between new energy stations and power systems, the sharing method of capacity electricity charges between photovoltaic stations and wind power stations of new energy stations, and the second sharing mechanism.

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

[0017] A service scenario determination module, used to determine the service scenario 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;

[0018] A simulation model building module is used to build a time-series production simulation model; the time-series production simulation model includes: an objective function and constraints; the objective function is built with the goal of maximizing the absorption of new energy stations by the pumped storage power 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;

[0019] 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 largest consumption of the new energy station;

[0020] A first allocation module, for determining, when the service scenario of the pumped storage power station is the first scenario, an allocation result of the capacity cost of the pumped storage power station on the user side by adopting a first allocation mechanism based on the optimal solution; 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 according to a voltage level;

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

[0022] A third allocation module is used for, when the service scenario of the pumped storage power station is the third scenario, based on the optimal solution, using a third allocation mechanism 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 method of the capacity electricity fee between the new energy station and the power system, the allocation method of 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 allocation module is used to determine the allocation result of the capacity cost of the pumped-storage power station on the user side based on the optimal solution by adopting the fourth allocation mechanism when the service scenario of the pumped-storage power station is the fourth scenario; the fourth allocation mechanism is determined according to the allocation method of the capacity electricity fee between the new energy station and the power system, the allocation method of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station, and the second allocation 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 embodiments of the present application or the technical solutions in the prior art, the drawings required for use in the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0028] Figure 1 This is an application environment diagram of a method for allocating capacity costs of a pumped storage power station on the user side in one embodiment of the present application;

[0029] Figure 2 A flow chart of a method for allocating capacity costs of a pumped storage power station on the user side provided in one embodiment of the present application;

[0030] Figure 3 A schematic diagram of an overall implementation process of a method for allocating capacity costs of a pumped storage power station on the user side in a practical application provided by an embodiment of the present application;

[0031] Figure 4 for Figure 3 Schematic diagram of the detailed process of the scenario of the impact of the medium-sized pumped storage capacity electricity fee sharing mechanism on the user's electricity price;

[0032] Figure 5 A schematic diagram of functional modules of a device for allocating capacity costs of a pumped storage power station on the user side provided in another embodiment of the present application;

[0033] Figure 6 A schematic diagram of the structure of a computer device provided in one embodiment of the present application. DETAILED DESCRIPTION

[0034] 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.

[0035] In order to make the above-mentioned objects, features and advantages of the present application more obvious and easy to understand, the present application is further described in detail below with reference to the accompanying drawings and specific implementation methods.

[0036] The method for allocating the capacity cost of a pumped storage power station on the user side provided in the embodiment of the present application can be applied to Figure 1In the application environment shown, the terminal 102 communicates with the server 104 through a network. The data storage system can store data that the server 104 needs to process. The data storage system can be set up separately, integrated on the server 104, or placed on the cloud or other servers. The terminal 102 can send the service scenario and the sequential production simulation model of the pumped-storage power station to the server 104. After receiving the service scenario and the sequential production simulation model of the pumped-storage power station, the server 104 solves the sequential production simulation model for the service scenario and the sequential production simulation model of the pumped-storage power station to obtain the optimal solution; when the service scenario of the pumped-storage power station is the first scenario, based on the optimal solution, the first allocation mechanism is used to determine the allocation result of the capacity cost of the pumped-storage power station on the user side; 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; when the service scenario of the pumped-storage power station is the third scenario, based on the optimal solution, the third allocation mechanism is used to determine the allocation result of the capacity cost of the pumped-storage power station on the user side; when the service scenario of the pumped-storage power station is the fourth scenario, based on the optimal solution, the fourth allocation mechanism is used to determine the allocation result of the capacity cost of the pumped-storage power station on the user side.

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

[0038] The terminal 102 may be, but is not limited to, various desktop computers, laptop computers, smart phones, tablet computers, IoT devices, and portable wearable devices. The IoT devices may be smart speakers, smart TVs, smart air conditioners, smart vehicle-mounted devices, etc. The portable wearable devices may be smart watches, smart bracelets, head-mounted devices, etc. The server 104 may be implemented as an independent server or a server cluster consisting of multiple servers, or may be a cloud server.

[0039] In an exemplary embodiment, Figure 2 As shown, a method for allocating the capacity cost of a pumped storage power station on the user side is provided. The method is executed by a computer device, and can be executed by a computer device such as a terminal or a server alone, or by a terminal and a server together. In the embodiment of the present application, the method is applied to Figure 1The server 104 in the example is used for explanation, and the steps include 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, constructing a sequential production simulation model.

[0045] Among them, 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 new energy stations; 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 largest 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 the 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 sharing mechanism and the voltage level sharing mechanism.

[0049] Step 205: 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 cost of the pumped-storage power station on the user side.

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

[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 cost of the pumped-storage power station on the user side.

[0052] Among them, the third sharing mechanism is determined according to the sharing method of capacity electricity charges between new energy stations and power systems, the sharing method of capacity electricity charges between photovoltaic stations and wind power stations of new energy stations, and the first sharing 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 cost of the pumped-storage power station on the user side.

[0054] Among them, the fourth sharing mechanism is determined based on the sharing method of capacity electricity charges between new energy stations and the power system, the sharing method of capacity electricity charges between photovoltaic stations and wind power stations of new energy stations, and the second sharing mechanism.

[0055] The implementation of the above-mentioned steps 201 to 207 can fairly and reasonably distribute the pumped storage capacity electricity charges on the user side, which can not only reduce the sharing pressure on the user side, but also effectively improve the cost recovery efficiency 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, the capacity electricity fee recovery mechanism is used to determine the capacity electricity fee of the pumped-storage power station borne by the regional power grid, or the output and profit sharing mechanism of the pumped-storage unit in the optimal solution is used to determine the capacity electricity fee of the pumped-storage power station borne by the regional power grid.

[0058] (2) Based on the capacity electricity charges of the pumped-storage power station borne by the 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; the increase in electricity prices for users in the regional power grid serves as the sharing result of the capacity charges 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, the capacity electricity fee of the pumped-storage power station borne by each of the multiple regional power grids is determined by allocating the capacity electricity fee among the regional power grids.

[0061] (2) 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 sharing result of the capacity charges of the pumped-storage power station on 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 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 the method of allocating the capacity electricity fee between the new energy station and the power system.

[0064] (2) 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 are used to 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.

[0065] (3) 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 capacity electricity charges of the pumped-storage power station borne by the photovoltaic station, the capacity electricity charges 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 sharing results of the capacity costs of the pumped-storage power station on 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 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 are determined by the method of allocating the capacity electricity fee between the new energy station and the power system.

[0068] (2) 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 are used to 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.

[0069] (3) 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.

[0070] (4) 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 stations. The capacity electricity charges of the pumped-storage power stations borne by the photovoltaic stations, the capacity electricity charges of the pumped-storage power stations borne by the wind farms, and the increase in electricity prices for users in each regional power grid serve as the sharing result of the capacity charges of the pumped-storage power stations on the user side in the fourth scenario.

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

[0072]

[0073] 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; It is the annual capacity electricity price approved in the regulatory cycle of the yth year.

[0074] The revenue sharing mechanism is expressed as:

[0075]

[0076] Among them, p cgdm Q is the price difference income of the pumped-storage power station; mg is the power generation of the mth pumped storage unit; p mg is the annual average settlement price of the pumped storage unit during the peak period; Q md is the pumped electricity of the mth pumped storage unit; p md The annual average settlement price of the pumped storage unit during the off-peak period; 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.

[0077] The expression for the allocation of capacity electricity charges among regional power grids is:

[0078]

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

[0080] The expression for the allocation of capacity electricity charges between new energy stations and the power system is:

[0081]

[0082] 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; wv The proportion of unit capacity allocated to new energy stations; It is the capacity electricity fee of the pumped storage power station PSD in the third scenario in a certain year.

[0083] The expression of the user amortization mechanism is:

[0084]

[0085] 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 power grid n.

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

[0087]

[0088] in, The increase in electricity price for users of 1 to 10 (20) kV; The increase in electricity prices for users of 35-110 kV; The increase in electricity price for users with a voltage greater than or equal to 220 kV; The apportionment ratio for users of 1 to 10 (20) kV; The apportionment ratio for users of 35 to 110 kV; The apportionment ratio for users with voltage greater than or equal to 220 kV; Annual electricity consumption of 1 to 10 (20) kV users; The annual power consumption of 35-110 kV users; The annual electricity consumption of users greater than or equal to 220 kV.

[0089] The allocation method of capacity electricity fee between photovoltaic stations and wind power stations in new energy stations is as follows:

[0090]

[0091] Among them, p wgdm The capacity electricity fee of the pumped storage power station borne by the wind farm; vgdm The capacity electricity fee of the pumped storage power station borne by the photovoltaic station; ΔQ w is the wind farm power consumed by the pumped storage power station; ΔQ vis the photovoltaic power generation 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 consumption 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 is consumed and the wind and solar power abandonment rate is reduced by reducing the output of conventional units or switching pumped storage units to pumping conditions. Therefore, with the maximum consumption of new energy stations as the goal, 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 wind farm and photovoltaic farm at time t.

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

[0098] (1) Power balance constraints:

[0099]

[0100] Where 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 hth 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 received power is a negative value.

[0101] (2) System capacity constraints:

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

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

[0104] (3) System external power constraints:

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

[0106] Where P smax (t), P smin (t) is the upper and lower limits of the planned power transmission of the system at time t, that is, the maximum transmission capacity of a regional power system to exchange power with the outside through the interconnection line. If the value is positive, it means power is transmitted to the outside, which belongs to the sending-end power grid, otherwise it belongs to the receiving-end power grid.

[0107] (4) Output constraints of new energy units:

[0108] 0≤P w (t)≤N w P * w (t) (13)

[0109] 0≤P v (t)≤N v P * v (t) (14)

[0110] Where N w is the installed capacity of wind power, 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 photovoltaic output at time t.

[0111] (5) Output constraints of thermal power units:

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

[0113] Where 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 constraints:

[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 hth 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 capacity constraints:

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

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

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

[0130]

[0131] Where, T mmax is the maximum full-load hours of the mth unit in the dispatching period, T D is the simulation step size, λ mgd For the extraction conversion efficiency.

[0132] For units with daily or weekly cycles, the upper reservoir water level at the start and end of the period should be consistent, that is:

[0133]

[0134] Combine the following Figure 3 and Figure 4 Taking the provincial power grid as an example of a regional power grid, this paper introduces the implementation process of a method for allocating the capacity cost of pumped storage power stations on the user side in practical applications.

[0135] S1: Sort out the current mechanism for sharing and guiding the capacity electricity charges of pumped storage power plants. According to relevant documents, the capacity electricity price of a pumped storage power station in a certain regulatory cycle is determined according to the operating period pricing method. In the regulatory cycle of the initial pricing, the annual capacity electricity fee is equal to the capacity electricity price multiplied by the installed capacity of the power station. If the pumped storage power station participates in the power auxiliary service market and obtains profits through price arbitrage in the initial regulatory cycle, 20% of these profits will be shared by the pumped storage power station in the next regulatory cycle and deducted when the capacity electricity price is determined; if no profit is obtained, but a loss is incurred, the pumped storage power station will bear the loss by itself, and the capacity electricity price will be consistent with the pricing in the initial regulatory cycle. For a pumped storage power station, if it serves multiple provincial power grids, the capacity electricity fee will be shared among the provincial power grids according to a certain ratio; if it serves new energy sites and power systems, the capacity electricity fee will also be shared between the two according to a certain ratio. The capacity electricity fee borne by the power grid or power system will be shared with industrial and commercial users in its area. Specifically:

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

[0137] The relevant opinions proposed that the capacity electricity fee corresponding to the approved pumped storage capacity electricity price should be paid by the power grid enterprises and included in the provincial power grid transmission and distribution price recovery. Another relevant opinion approved the capacity electricity price of 48 power stations in operation and planned to be put into operation before the end of 2025. The capacity electricity fee of the pumped storage power station in the yth year is shown in formula (1), which will not be elaborated here.

[0138] (2) Sort out relevant benefit-sharing mechanisms.

[0139] Relevant opinions point out that 20% of the ancillary service income and the power generation price difference income generated by the power station in the previous regulatory cycle will be shared by the pumped storage power station, and 80% will be deducted accordingly when the power station capacity electricity price is determined in the next regulatory cycle, and the losses will be borne by the pumped storage power station. In order to highlight the role of pumped storage in absorbing new energy, it is assumed that 100% of the capacity of the pumped storage power station participates in the system peak regulation and arbitrage is carried out in the spot market through the power generation price difference. The average annual power generation price difference income of the pumped storage power station is shown in formula (2), which will not be repeated here.

[0140] As the relevant opinions do not provide detailed rules for deducting the price difference income from pumping, the price difference income of this year is temporarily included in the capacity electricity fee income of the power station in the next year. The capacity electricity fee of the pumped storage power station in the y+1 year is as shown in formula (3), which will not be elaborated here.

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

[0142] The Opinions on the Pumped Storage Pricing Mechanism proposes to clarify the proportion of capacity electricity charges among regions based on the functions and services of pumped storage. If a pumped storage power station PSC serves N provincial grids, the capacity electricity charges borne by each provincial grid are as shown in formula (4), which will not be elaborated here.

[0143] (4) Clarify how capacity charges are allocated between specific power sources and power systems.

[0144] The relevant opinions propose that the project should clarify the capacity sharing ratio of the capacity electricity fee between the specific power source and the power system according to the approval documents. Assume that the specific power source is a large-scale wind and solar base. If the pumped storage power station PSD (the pumped storage power station in the third scenario) serves the new energy station and the power system, the capacity electricity fee borne by both is shown in formula (5), which will not be repeated here.

[0145] S2: Design scenarios for the impact of pumped storage capacity charges on user electricity prices. The allocation of pumped storage capacity charges 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 power grid, and the capacity electricity charges of the power station are all borne by users in the province. Scenario 2 (i.e. the second scenario): The pumped storage power station PSC serves multiple provincial power grids. The capacity electricity charges are first allocated among the provincial power grids according to the inter-provincial ratio, and then transmitted to users in each province. Scenario 3 (i.e. the third scenario): The pumped storage power station PSD serves a specific power source and a single provincial power grid. The capacity electricity charges are first allocated between the power source and a provincial power grid according to the capacity ratio, 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 power grids. The capacity electricity fee is first shared between the power source and multiple provincial power grids according to the capacity ratio. The part borne by the provincial power grid is then shared among the provincial power grids according to the inter-provincial ratio, and finally transmitted to the user side of each province. Specifically:

[0146] (1) Design scenarios where the electricity charges for all pumped storage capacity are apportioned to users (Scenario 1 and Scenario 3).

[0147] At present, the electricity price for industrial and commercial users consists of five parts: grid-connected electricity price, grid-connected line loss fee, transmission and distribution price, system operation fee, and fund and surcharge. The pumped storage capacity fee is calculated on a provincial basis, listed separately outside the transmission and distribution price, and included in the user system operation fee. If it is shared equally by all users, the increase in the electricity price for users in the provincial grid n is as shown in formula (6), which will not be described in detail here.

[0148] At present, the transmission and distribution costs are shared among users of different electricity price levels. Specifically, the transmission and distribution prices of users of different voltage levels are different. The higher the voltage level, the lower the transmission and distribution price, and the less the shared cost, and vice versa. Referring to the sharing of transmission and distribution costs, it is unfair to users of high voltage levels to share the pumped storage capacity electricity fee. Therefore, this application divides users into three levels according to the voltage level, and sets different sharing coefficients for each level. The increase in user electricity prices is shown in formula (7), which will not be repeated here.

[0149] (2) Design scenarios in which electricity charges for part of the pumped storage capacity are apportioned to users (Scenario 2 and Scenario 4).

[0150] In this case, the pumped storage capacity electricity fee is first apportioned between the new energy station and the power system according to the capacity ratio, and the part borne by the power system is then transmitted to the user side. The user's electricity price increase can be calculated by formula (6) or formula (7), which will not be repeated here. The part borne by the new energy can be apportioned among wind power and photovoltaic power according to the role of pumped storage in absorbing new energy. Through the power system simulation method, the increase in wind power and photovoltaic power generation before and after the pumped storage station is incorporated into the power system is calculated to quantify the different degrees of absorption of the two by pumped storage, and then set the apportionment ratio of the capacity electricity fee between the two. The capacity electricity fee to be shared by wind power and photovoltaic power is shown in formula (8), which will not be repeated here.

[0151] S3: Construct an allocation model based on the time series production simulation method (i.e., a time series production simulation model). The time series production model can be solved by using MATLAB software in conjunction with CPLEX, and the results obtained are brought into the allocation scenarios designed in S2, thereby obtaining the allocation results under four allocation scenarios.

[0152] In order to improve the fairness and rationality of the allocation of capacity electricity charges on the user side, the above-mentioned embodiment realizes the allocation of capacity electricity charges on the user side based on the allocation model of pumped storage capacity electricity charges on the user side based on the time series production simulation method. First, the capacity electricity charge allocation and guidance mechanism of pumped storage power stations at this stage is sorted out, and then the allocation scenarios on the user side are designed. Finally, the allocation results of capacity electricity charges in various scenarios are calculated through the time series production simulation method. The mentioned method can fairly and reasonably allocate and guide the pumped storage capacity electricity charges 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 pumped storage power stations.

[0153] This application quantifies the impact of the pumped storage capacity electricity fee sharing mechanism on user electricity prices, and finds that the installed capacity, capacity price, income level, cost sharing and guidance method of the pumped storage power station, and the user-side sharing standard all have an impact on user electricity prices. Since the capacity cost accounts for a large proportion of the total cost of the pumped storage power station, with the large-scale construction and development of pumped storage, a perfect pricing mechanism and a fair and reasonable cost sharing and guidance method can not only reduce the user-side electricity price burden, but also help improve the cost recovery efficiency of the pumped storage power station. The simulation results show that:

[0154] (1) At present, the revenue of pumped-storage power stations is affected by factors such as limited arbitrage space for the price difference between pumping and power generation in the spot market and imperfect market mechanisms for auxiliary services. The overall revenue is low, and some power stations may even incur losses. With the construction and development of the power market, the space for various revenues will increase, and the capacity electricity price will be further reduced. It is recommended that in the next stage, local governments adopt the profit model of "capacity electricity price units + market-oriented units" according to the actual operation of power stations. That is, the power station reserves some units that undertake the "bottom line" task and settles according to the approved capacity electricity price, and the remaining units participate in the market, thereby improving the overall economic benefits of pumped-storage power stations, reducing the annual capacity electricity fee, and further increasing the efficiency of recovering the cost of pumped-storage power stations.

[0155] (2) According to the simulation results, the method of apportionment and guidance of pumped storage capacity electricity charges can be improved from the following three aspects. First, for provinces and regions with closely connected grid structures, it is possible to consider developing "shared pumped storage power stations" and let the provincial grid companies independently negotiate the apportionment ratio. While optimizing regional resource allocation, the user electricity price can be reduced by expanding the apportionment scope. Second, for provinces with concentrated pumped storage resources, it is possible to consider reducing the cost of dredging to the user side by configuring a certain scale of new energy stations to bear part of the capacity electricity charges, so as to achieve a win-win situation of "increased new energy consumption and reduced user-side electricity price increase"; third, for areas where geological conditions permit, while building large-scale integrated wind and solar base projects, it is possible to consider reserving supporting pumped storage power stations to enhance the autonomous regulation capacity of integrated large base projects. The pumped storage capacity electricity charges are absorbed within the project or the wind, solar and storage bases are used as a whole to determine the comprehensive on-grid electricity price. The capacity electricity charges are no longer transmitted to the user side, further reducing the pressure on user electricity prices.

[0156] (3) According to the simulation results, it is recommended that a two-level allocation index system be considered for the user side. The first level classifies the user side according to the voltage level. The higher the voltage level, the less the user uses the transmission and distribution resources, and the smaller the allocation weight is set; the second level is for users of the same voltage level, divided into 2-5 levels according to the degree of fluctuation of the user load within a certain period of time. The more drastic the load fluctuation, the higher the user's use of system regulation resources, and the larger the allocation weight is set. Through the two-level allocation index system, the user side classification is refined to ensure that the capacity electricity fee of the pumped storage power station is fairly and reasonably allocated among users.

[0157] Based on the same inventive concept, the embodiment of the present application also provides a device for allocating the capacity cost of a pumped storage power station on the user side for realizing the method for allocating the capacity cost of a pumped storage power station on the user side involved in the above-mentioned method. The implementation scheme for solving the problem provided by the device is similar to the implementation scheme recorded in the above-mentioned method, so the specific limitations in the embodiments of one or more devices for allocating the capacity cost of a pumped storage power station on the user side provided below can be referred to the limitations of the method for allocating the capacity cost of a pumped storage power station on the user side above, and will not be repeated here.

[0158] In an exemplary embodiment, Figure 5 As shown, a device for allocating the capacity cost of a pumped storage power station on the user side is provided, comprising:

[0159] The service scenario determination module 301 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.

[0160] The simulation model construction module 302 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 of new energy sites by the pumped-storage power station; the constraints include: power balance constraints, system capacity constraints, system transmission power constraints, new energy site 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.

[0161] The solution module 303 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 largest absorption capacity for the new energy station.

[0162] The first allocation module 304 is used to determine the allocation result of the capacity cost of the pumped-storage power station on the user side based on the optimal solution when the service scenario of the pumped-storage power station is the first scenario, using the first allocation mechanism; the first allocation mechanism is determined according to the capacity electricity fee recovery mechanism, the profit sharing mechanism, the user equalization mechanism and the voltage level allocation mechanism.

[0163] The second allocation module 305 is used to determine the allocation result of the capacity cost of the pumped-storage power station on the user side by adopting the second allocation mechanism when the service scenario of the pumped-storage power station is the second scenario; the second allocation mechanism is determined according to the allocation method of the capacity electricity fee among the regional power grids, the user sharing mechanism and the voltage level allocation mechanism.

[0164] The third allocation module 306 is used to determine the allocation result of the capacity cost of the pumped-storage power station on the user side based on the third allocation mechanism when the service scenario of the pumped-storage power station is the third scenario, based on the optimal solution; the third allocation mechanism is determined according to the allocation method of the capacity electricity fee between the new energy station and the power system, the allocation method 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 used to determine the allocation result of the capacity cost of the pumped-storage power station on the user side based on the fourth allocation mechanism when the service scenario of the pumped-storage power station is the fourth scenario, based on the optimal solution; the fourth allocation mechanism is determined according to the allocation method of the capacity electricity fee between the new energy station and the power system, the allocation method 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 is provided. The computer device may be a server or a terminal. The internal structure diagram thereof may be as follows: Figure 6 As shown. The computer device includes a processor, a memory, an input / output interface (Input / Output, referred to as I / O) and a communication interface. Among them, 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. Among them, the processor of the computer device is used 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 used to store service scenarios and time-series production simulation models of pumped storage power stations. The input / output interface of the computer device is used to exchange information between the processor and an external device. The communication interface of the computer device is used to communicate with an external terminal through a network connection. When the computer program is executed by the processor, a method for allocating the capacity cost of a pumped storage power station on the user side is implemented.

[0167] Those skilled in the art will understand that Figure 6The structure shown in the figure is only a block diagram of a part of the structure related to the solution of the present application, and does not constitute a limitation on the computer device to which the solution of the present application is applied. The specific computer device may 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 further provided, including a memory and a processor, wherein a computer program is stored in the memory, and the processor implements the steps in the above-mentioned method embodiments when executing the computer program.

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

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

[0171] Those of ordinary skill in the art can understand that all or part of the processes in the above-mentioned embodiment methods can be completed by instructing the relevant hardware through a computer program, and the computer program can be stored in a non-volatile computer-readable storage medium. When the computer program is executed, it can include the processes of the embodiments of the above-mentioned methods. Among them, any reference to the memory, database or other medium used in the embodiments provided in the present application can include at least one of non-volatile and volatile memory. Non-volatile memory can include read-only memory (ROM), magnetic tape, floppy disk, flash memory, optical memory, high-density embedded non-volatile memory, resistive random access memory (ReRAM), magnetic random access memory (MRAM), ferroelectric random access memory (FRAM), phase change memory (PCM), graphene memory, etc. Volatile memory can include random access memory (RAM) or external cache memory, etc. By way of illustration and not limitation, RAM may be in various forms, such as static random access memory (SRAM) or dynamic random access memory (DRAM).

[0172] The database involved in each embodiment provided in this application may include at least one of a relational database and a non-relational database. The non-relational database may include a distributed database based on blockchain, etc., but is not limited thereto. The processor involved in each embodiment provided in this application may be a general-purpose processor, a central processing unit, a graphics processor, a digital signal processor, a programmable logic device, etc., but is not limited thereto.

[0173] The technical features of the above embodiments may be combined arbitrarily. To make the description concise, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.

[0174] This article uses specific examples to illustrate the principles and implementation methods of this application. The description of the above embodiments is only used to help understand the method and core ideas of this application. At the same time, for those skilled in the art, according to the ideas of this application, there will be changes in the specific implementation methods and application scope. In summary, the content of this specification should not be understood as limiting this application.

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 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; 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 of new energy stations by the pumped-storage power 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 largest consumption of 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 the capacity electricity fee recovery mechanism, the revenue sharing mechanism, the user equalization mechanism and the voltage level allocation mechanism; 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; the second allocation mechanism is determined according to the allocation method of the capacity electricity fee among the regional power grids, the user equalization mechanism and the allocation mechanism according to the voltage level; When the service scenario of the pumped storage power station is the third scenario, based on the optimal solution, a third allocation mechanism is adopted to determine the allocation result of the capacity fee of the pumped storage power station on the user side; the third allocation mechanism is determined according to the allocation method of the capacity electricity fee between the new energy station and the power system, the allocation method of the capacity electricity fee between the photovoltaic station and the wind farm station of the new energy station, and the first allocation 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 capacity electricity charges between new energy stations and power systems, the sharing method of capacity electricity charges between photovoltaic stations and wind power stations of new energy stations, and the second sharing mechanism.

2. The method for allocating the capacity cost 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, the 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 of the pumped-storage power station borne by the regional power grid is determined by using the capacity electricity fee recovery mechanism, or the output and revenue sharing mechanism of the pumped-storage unit in the optimal solution is used to determine the capacity electricity fee of the pumped-storage power station borne by the regional power grid; According to the capacity electricity charge of the pumped-storage power station borne by the 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; the increase in electricity prices for users in the regional power grid serves as the result of sharing the capacity cost of the pumped-storage power station on the user side in the first scenario.

3. The method for allocating the capacity cost 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 Q is the price difference income of the pumped-storage power station; mg is the power generation of the mth pumped storage unit; p mg is the annual average settlement price of the pumped storage unit during the peak period; Q md is the pumped electricity of the mth pumped storage unit; p md The annual average settlement price of the pumped storage unit during the off-peak period; 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 power grid n; The expression of the voltage level allocation mechanism is: in, The increase in electricity prices for users of 1 to 20 kV; The increase in electricity prices for users of 35-110 kV; The increase in electricity price for users with a 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 to 110 kV; The apportionment ratio for users with voltage greater than or equal to 220 kV; Annual power consumption of 1-20 kV users; The annual power consumption of 35-110 kV users; The annual electricity consumption of users greater than or equal to 220 kV.

4. The method for allocating the capacity cost 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 using the 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 the capacity cost of a pumped storage power station on the user side according to claim 4, characterized in that: The expression for the allocation of 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 power 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 the capacity cost 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 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 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; 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 are used to 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; According to the capacity electricity charge of the pumped-storage power station borne by the regional power grid, the increase in electricity prices for users in the regional power grid is determined by a user equalization mechanism or a voltage level sharing mechanism; 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 serve as the result of sharing the capacity cost of the pumped-storage power station on the user side in the third scenario.

7. The method for allocating the capacity cost 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; 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 allocation method of capacity electricity fee between photovoltaic stations and wind power stations in new energy stations is as follows: Among them, p wgdm The capacity electricity fee of the pumped storage power station borne by the wind farm; vgdm The capacity electricity fee of the pumped storage power station borne by the photovoltaic station; ΔQ w is the wind farm power consumed by the pumped storage power station; ΔQ v is the photovoltaic power generation 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 the capacity cost 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 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 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 the method of allocating the capacity electricity fee between the new energy station and the power system; 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 are used to 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; According to 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 the 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 a user equalization mechanism or a voltage level sharing mechanism based on the corresponding capacity electricity charges of the pumped-storage power station. The capacity electricity charges of the pumped-storage power station borne by the photovoltaic station, the capacity electricity charges of the pumped-storage power station borne by the wind farm, and the increase in electricity prices for users in each regional power grid serve as the result of sharing the capacity costs of the pumped-storage power station 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, used to determine the service scenario 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 building module is used to build a time-series production simulation model; the time-series production simulation model includes: an objective function and constraints; the objective function is built with the goal of maximizing the absorption of new energy stations by the pumped storage power 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 largest consumption of the new energy station; A first allocation module, for determining, when the service scenario of the pumped storage power station is the first scenario, an allocation result of the capacity cost of the pumped storage power station on the user side by adopting a first allocation mechanism based on the optimal solution; 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 according to a voltage level; A second allocation module, for, when the service scenario of the pumped storage power station is the second scenario, using a second allocation mechanism to determine the allocation result of the capacity cost of the pumped storage power station on the user side; the second allocation mechanism is determined according to the allocation method of the capacity electricity fee among the regional power grids, the user equalization mechanism and the voltage level allocation mechanism; A third allocation module is used for, when the service scenario of the pumped storage power station is the third scenario, based on the optimal solution, using a third allocation mechanism 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 method of the capacity electricity fee between the new energy station and the power system, the allocation method of 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 allocation module is used to determine the allocation result of the capacity cost of the pumped-storage power station on the user side based on the optimal solution by adopting the fourth allocation mechanism when the service scenario of the pumped-storage power station is the fourth scenario; the fourth allocation mechanism is determined according to the allocation method of the capacity electricity fee between the new energy station and the power system, the allocation method of the capacity electricity fee between the photovoltaic station and the wind power station of the new energy station, and the second allocation mechanism.

10. 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 the method for allocating the capacity cost of a pumped-storage power station on the user side as described in any one of claims 1 to 8.

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