Market-considered pumped storage power station cost dredging strategy establishment method

Abstract

The invention relates to a method for establishing a pumped storage power station cost dredging strategy considering the market. According to the method, the market development stage is divided into a market initial stage, a market middle stage and a market mature stage according to the market participation degree of a pumped storage power station; establishing a price model corresponding to the initial market stage as a two-part electricity price mechanism based on the market development stage of the pumped storage power station; the price model corresponding to the middle stage of the market is a fixed income and variable bidding mechanism; the price model corresponding to the market mature period is a marketization price mechanism; and finally, establishing a cost dredging strategy of the pumped storage power station corresponding to each market development stage based on the price model of each market development stage of the pumped storage power station, thereby improving the economic benefit and sustainable development capability of the pumped storage power station.

Description

Technical Field

[0001] The invention relates to a method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration, and belongs to the technical field of cost diversion for power stations. Background Art

[0002] With the development of renewable energy, the role of pumped storage power stations has become more prominent. In order to optimize resource allocation, reduce costs, improve economic benefits, enhance the competitiveness of power stations in the power market, and ensure their sustainable development, the existing cost diversion strategies for pumped storage power stations mainly include electricity price mechanisms, government support and subsidies, and investment and integration mechanisms:

[0003] The electricity price mechanism is to encourage pumped storage power stations to pump water during off-peak hours and generate electricity during peak hours through the difference between peak electricity prices and off-peak electricity prices, thereby maximizing economic benefits. Its advantages are significant economic benefits and strong regulatory capabilities, but its disadvantages are that the uncertainty of electricity market prices may affect profits and need to face market risks.

[0004] Government support and subsidies refer to the government providing financial subsidies for the construction and operation of pumped storage power stations to reduce their financial pressure or reduce the operating costs of pumped storage power stations and improve their economic efficiency through tax reduction and exemption. Obviously, the disadvantage of this strategy is that over-reliance on government subsidies may lead to a lack of motivation for independent innovation in enterprises.

[0005] Although the existing cost-relief strategy for pumped-storage power stations has advantages in optimizing resource allocation and improving economic benefits, it does not take into account the relationship between the benefits of pumped-storage power stations participating in the market at different stages of market development and government support and subsidies, resulting in its unclear positioning and operating model in the market. Summary of the invention

[0006] In order to solve the problem that the cost diversion strategy in the prior art does not take into account the different development stages of the market, the present invention provides a method for establishing a cost diversion strategy based on the market development stage of a pumped storage power station.

[0007] In order to achieve the above-mentioned purpose, the technical solution proposed by the present invention is: a method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration, comprising:

[0008] According to the degree of market participation of pumped storage power stations, the market development stage is divided into the early market stage, the middle market stage and the mature market stage;

[0009] Based on the market development stage of pumped storage power stations, the price model corresponding to the initial stage of the market is a two-part electricity price mechanism; the price model corresponding to the mid-term market is a fixed income combined with a variable bidding mechanism; the price model corresponding to the mature stage of the market is a market-based price mechanism;

[0010] Based on the price model of each market development stage of pumped-storage power stations, a cost diversion strategy for pumped-storage power stations corresponding to each market development stage is established.

[0011] The further design of the above technical solution is as follows: the stage when the pumped storage power station does not participate in the market corresponds to the early stage of the market, the stage when it participates in the market but is not fully commercialized corresponds to the mid-stage of the market, and the stage of full marketization corresponds to the mature stage of the market.

[0012] The two-part electricity price mechanism is the quantity electricity price and the capacity electricity price.

[0013] The electricity price model W cap for:

[0014] W en =C en E

[0015] Among them, C en is the electricity price, E is the electricity consumption of the user;

[0016] Capacity price model W cap for:

[0017] W cap =C cap D max

[0018] Among them, C cap is the capacity price, D max The maximum demand of the user.

[0019] In the mid-term price model of the market, the fixed income part is settled by a two-part electricity price mechanism; the variable bidding part is settled by pumped energy storage participating in peak and frequency regulation;

[0020] The price model W corresponding to the variable bidding part freq for:

[0021]

[0022] in, represents the frequency modulation price, E cp It is the capacity involved in frequency modulation.

[0023] The price model in the mature stage of the market is settled by participating in the ancillary service market, specifically:

[0024] W=W com +W res

[0025] Where W represents the ancillary service market revenue; W com and W res denote the frequency regulation and reserve auxiliary market revenues respectively;

[0026]

[0027] Among them, D t , and represents the frequency modulation mileage, the winning frequency modulation capacity and the frequency modulation mileage price in period t respectively; B cp is the frequency regulation capacity price; K and T are the comprehensive frequency regulation index and the metering period respectively;

[0028]

[0029] in: and They represent the winning bid and calling of spare capacity at time t, represents the spot market electricity price; B res is the spare capacity price.

[0030] The cost diversion strategy in the initial stage of the market is to divert the cost to the user side based on a two-part electricity price.

[0031] The mid-term cost management strategy model for the market is:

[0032]

[0033]

[0034] Among them: F i and W i fix They represent the on-grid transaction electricity and fixed income sharing expenses borne by the power generation entity i respectively; and F c They represent the fixed cost and electricity consumption of user c respectively; η1 is the proportion of fixed income to shared expenses.

[0035] The cost diversion strategy model for the mature market stage is:

[0036]

[0037] R c =(1-η2)WF c

[0038] Where: R i represents the auxiliary service cost borne by the power generation entity i; R total and R c They represent the total ancillary service costs and the ancillary service share costs on the user side respectively; η2 is the ancillary service share ratio on the power generation side.

[0039] The beneficial effects of the present invention are:

[0040] The present invention divides the market stages according to the degree of market participation of the pumped-storage power station, fully considers the characteristics of the markets at different stages, and compares the characteristics of different price formation mechanisms, so as to provide a basis for formulating a pumped-storage cost diversion strategy; the cost diversion strategy of the pumped-storage power station at different market stages constructed according to the price formation at each stage is more reasonable, and the positioning and operation mode in the market are clearer, thereby improving the economic benefits and sustainable development capabilities of the pumped-storage power station, and providing a feasible solution for the marketization process of the pumped-storage power station.

[0041] The pricing mechanism established by the present invention comprehensively considers factors such as electricity purchase cost, energy storage income, ancillary service income and policy subsidies, and is more scientific and reasonable. It can not only effectively reflect the scarcity and supply and demand relationship of resources, but also promote the rational allocation and effective utilization of resources, thereby providing a clear direction and basis for the formulation and implementation of cost relief methods. BRIEF DESCRIPTION OF THE DRAWINGS

[0042] Figure 1 This is a schematic diagram of the two-part electricity price mechanism;

[0043] Figure 2 It is the installed capacity diagram of each unit in the power system;

[0044] Figure 3 This is a diagram of the pumped-storage power station's annual power generation. DETAILED DESCRIPTION

[0045] The present invention is described in detail below with reference to the accompanying drawings and specific embodiments.

[0046] Embodiment 1

[0047] The method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration of the present invention comprises the following steps:

[0048] According to the degree of market participation of pumped storage power stations, the market development stage is divided into the early market stage, the middle market stage and the mature market stage;

[0049] Based on the market development stage of pumped storage power stations, the price model corresponding to the initial stage of the market is a two-part electricity price mechanism; the price model corresponding to the mid-term market is a fixed income combined with a variable bidding mechanism; the price model corresponding to the mature stage of the market is a market-based price mechanism;

[0050] Based on the price model of each market development stage of pumped-storage power stations, a cost diversion strategy for pumped-storage power stations corresponding to each market development stage is established.

[0051] In the early stage of the pumped storage power station market, the government-set price was adopted to guide the market to users through the electricity sales price.

[0052] The mid-term cost management strategy for pumped storage power stations is based on government pricing and supplemented by the market, in which fixed income costs are shared by power generation companies and users;

[0053] The cost mitigation strategy in the mature stage of the pumped-storage power station market relies on the ancillary service market, and the ancillary service costs of pumped-storage power stations are shared by power generation and users.

[0054] Embodiment 2

[0055] The method for establishing the cost diversion strategy of the pumped storage power station considering the market in this embodiment is further designed on the basis of the first embodiment, and is specifically as follows:

[0056] Step 1: According to the maturity of electricity market rules and the degree of market participation of pumped storage power stations, the electricity market is divided into the initial, middle and mature stages. The characteristics of the three stages are as follows:

[0057] (1) Early stage of the market: In the early stage of the market, policies and mechanisms are not yet mature, market participants have low adaptability to market rules, and market prices fluctuate greatly. The operation of pumped-storage power stations is basically completely dependent on policies and subsidies; therefore, based on the above characteristics, this embodiment classifies the stage when pumped-storage power stations do not participate in the market as the early stage of the market.

[0058] (1) Mid-market stage: As the market mechanism gradually improves, in the mid-market stage, the participation of pumped-storage power stations gradually increases, and the price mechanism gradually matures, but it still requires some policy guidance and market subsidies to ensure its economic benefits; therefore, based on the above characteristics, this embodiment divides the stage in which pumped-storage power stations participate in the market but are not fully marketized into the mid-market stage.

[0059] (1) Market maturity stage: When the market enters the maturity stage, pumped-storage power stations can obtain sufficient economic benefits by independently participating in frequency regulation and peak load regulation services in the market. The market price is stable, the mechanism is fully market-oriented, and no additional policy subsidies are required to maintain operation. Therefore, based on the above characteristics, this embodiment corresponds the fully market-oriented stage of pumped-storage power stations to the market maturity stage.

[0060] Step 2: Based on the development stages divided above, this embodiment establishes a pumped storage electricity price model at different market development stages by comparing the advantages and disadvantages of different price models:

[0061] (1) In the early stage of the market, the high power generation loss of pumped storage units makes it difficult to recover costs. Therefore, this embodiment adopts a two-part electricity price mechanism at this stage, namely, the electricity price for quantity and the electricity price for capacity. The two-part electricity price mechanism ensures capacity benefits through government pricing. The two-part electricity price mechanism is as follows: Figure 1 As shown in the figure, in areas where spot markets are developed, the electricity volume and electricity price are settled according to prices and rules. The electricity volume and electricity price model Wcap for:

[0062] W en =C en E(1)

[0063] Among them, C en is the electricity price, and E is the electricity consumption of the user.

[0064] The capacity electricity price adopts an incentive pricing method of regular assessment and revenue sharing, and its model is:

[0065] W cap =C cap D max (2)

[0066] Among them, C cap is the capacity price, D max The maximum demand of the user.

[0067] (2) In the mid-term of the market, pumped storage power stations gradually participate in the ancillary service market. Compared with the previous two-part electricity price, the income of pumped storage power stations in the market has decreased, which brings challenges to the operation of power stations. In order to ensure the basic income of pumped storage power stations, this embodiment adopts the price mechanism of "fixed income + variable bidding". The fixed income part can adopt the two-part electricity price in the initial stage, and the variable bidding part participates in peak load regulation and frequency regulation through pumped storage. Its price model is

[0068]

[0069] in, represents the frequency modulation price, E cp It is the capacity involved in frequency modulation.

[0070] (3) In the mature market stage, market rules and market-based prices are basically complete. Pumped storage power stations can settle accounts through reactive power and black start auxiliary services, electric energy market, frequency regulation and standby auxiliary service market, etc. The settlement formula is as follows:

[0071] W=W com +W res (4)

[0072] Where W represents the ancillary service market revenue; W com and W res Represent the frequency regulation and reserve market revenues respectively.

[0073]

[0074] Where: D t , and represents the frequency modulation mileage, the winning frequency modulation capacity and the frequency modulation mileage price in period t respectively; Bcp is the frequency regulation capacity price; K and T are the comprehensive frequency regulation index and metering period respectively.

[0075] The backup ancillary service fee consists of two parts: backup capacity and actual electricity usage fee. The backup capacity fee refers to the fee incurred by the power supplier for a certain amount of backup capacity reserved to ensure the stable operation of the power system; the actual electricity usage fee refers to the fee calculated based on the actual electricity usage when the backup capacity is actually used. The model of the backup ancillary service fee is expressed as:

[0076]

[0077] in: and They represent the winning bid and the calling of spare capacity at time t, respectively, and represents the spot market electricity price; B res is the spare capacity price.

[0078] The advantages and disadvantages of the price formation mechanism of the pumped storage power station at different stages established in this embodiment are shown in Table 1:

[0079] Table 1 Comparison of different price formation mechanisms

[0080]

[0081] Step 3: Based on the electricity price models at different stages, further propose different relief mechanisms to reasonably allocate the cost of pumped storage to different objects.

[0082] Since the price formation mechanism of pumped storage is different in different market stages, its cost diversion method is also different. Therefore, this embodiment establishes a cost diversion model for pumped storage in each market stage:

[0083] (1) In the early stage of the market, since pumped-storage power stations adopted a two-part electricity price mechanism, the government-set pricing method was adopted to guide the electricity sales price to the user side.

[0084] (2) In the mid-term market, the cost diversion strategy for pumped storage power stations is mainly government pricing, supplemented by the market. Variable bidding is to divert the remaining capacity beyond the fixed income approved capacity to the power generation side through participation in the electric energy market and ancillary service market; the fixed income part is shared by the power grid company and the user according to the proportion of online transaction electricity, that is:

[0085]

[0086]

[0087] Where: F i and W ifix It represents the electricity volume and fixed income sharing costs borne by the power generation entity i; and F c They represent the fixed cost and electricity consumption of user c respectively; η1 is the proportion of shared costs.

[0088] (3) In the mature market stage, the cost of pumped storage power stations depends on the ancillary service market. The ancillary service costs of pumped storage power stations are shared by power generation and users. The specific shared costs are as follows:

[0089]

[0090] R c =(1-η2)WF c (10)

[0091] Where: R i represents the auxiliary service cost borne by the power generation entity i; R total and R c They represent the total ancillary service costs and the ancillary service share costs on the user side respectively; η2 is the ancillary service share ratio on the power generation side.

[0092] Application Examples

[0093] In this example, a pumped storage power station is selected as the research object. The installed capacity of each type of unit in the system and the power generation of the pumped storage power station are as follows: Figure 2 and Figure 3 According to the price formation model of the pumped storage power station proposed in the above embodiment, its revenue is estimated, and a cost guidance scheme is given, with a rate of return of 6.5% as the control condition for cost guidance. The construction investment of the pumped storage power station is 13.17 billion yuan, and the loan repayment period and operation period are 25 years and 40 years respectively.

[0094] a. Early stage of market

[0095] In the early stage of the market, the pumped storage power station adopts the two-part electricity price mentioned above, such as formula (1) and (2), and the revenue of the pumped storage power station can be calculated. The capacity electricity fee, power generation revenue and pumping cost are 1.523 billion yuan, 985 million yuan and 1.001 billion yuan respectively, and the annual net revenue is 1.507 billion yuan. Due to the government-priced guidance method, the revenue and cost of the power station are directly guided to the users and borne by each user.

[0096] b. Mid-term market

[0097] In the mid-term of the market, the pumped storage power station adopts the "fixed income + variable bidding" mechanism. If the capacity used for frequency regulation is 10%, the capacity electricity fee, power generation income, auxiliary frequency regulation income and pumping cost are 1.323 billion yuan, 885 million yuan, 232 million yuan and 1.001 billion yuan respectively. If the allocation coefficient η1 is 50%, according to the guidance model, users will share 1.522 billion yuan and new energy will share 1.922 billion yuan, of which photovoltaic power will account for 1.221 billion yuan and wind power will account for 701 million yuan.

[0098] c. Market maturity

[0099] In the mature stage of market development, pumped storage power stations settle accounts through the frequency regulation and standby ancillary service markets. Assuming that 20% and 50% of the pumped storage power station are used for frequency regulation and standby ancillary services, respectively, the average clearing price of frequency regulation capacity and frequency regulation mileage and the price of standby ancillary services are 35 yuan / MWh, 25 yuan / MW and 0.7 yuan / kWh respectively. According to the mature cost model, the annual net income of the system is 1.518 billion yuan, including 202 million yuan, 2.213 billion yuan and 104 million yuan of frequency regulation, standby and power generation income, and 1.001 billion yuan of pumping cost. In the mature stage of market development, the cost of pumped storage power stations mainly depends on the ancillary service market, which is shared by power generation and users. Assuming the sharing coefficient η2 is equal to 35%, the sharing result of ancillary service costs is 99 million yuan for wind power, 723 million yuan for photovoltaic power, and 1.593 billion yuan for the user side.

[0100] From this example, we can see that the proposed cost diversion strategy adopts corresponding cost diversion methods according to the different characteristics of the early, middle and mature stages of the market, which improves the economic benefits and market competitiveness of the power station; at the same time, it gradually reduces dependence on government subsidies and enhances the power station's independent profitability and sustainable development capabilities in the market; in addition, a reasonable cost sharing mechanism effectively reduces the financial pressure of the power station and optimizes operational stability and market adaptability.

[0101] The technical solutions of the present invention are not limited to the above-mentioned embodiments, and any technical solutions obtained by equivalent replacement methods fall within the scope of protection required by the present invention.

Claims

1. A method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration, characterized in that: include: According to the degree of market participation of pumped storage power stations, the market development stage is divided into the early market stage, the middle market stage and the mature market stage; Based on the market development stage of pumped storage power stations, the price model corresponding to the initial stage of the market is a two-part electricity price mechanism; the price model corresponding to the mid-term market is a fixed income combined with a variable bidding mechanism; the price model corresponding to the mature stage of the market is a market-based price mechanism; Based on the price model of each market development stage of pumped-storage power stations, a cost diversion strategy for pumped-storage power stations corresponding to each market development stage is established.

2. The method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration according to claim 1, characterized in that: The stage in which the pumped-storage power station does not participate in the market corresponds to the early stage of the market, the stage in which it participates in the market but is not fully commercialized corresponds to the middle stage of the market, and the stage in which it is fully commercialized corresponds to the mature stage of the market.

3. The method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration according to claim 1, characterized in that: The two-part electricity price mechanism is the quantity electricity price and the capacity electricity price.

4. The method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration according to claim 2, characterized in that: The electricity price model W cap for: W en =C en E Among them, C en is the electricity price, E is the electricity consumption of the user; Capacity price model W cap for: W cap =C cap D max Among them, C cap is the capacity price, D max The maximum demand of the user.

5. The method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration according to claim 4, characterized in that: In the mid-term price model of the market, the fixed income part is settled by a two-part electricity price mechanism; the variable bidding part is settled by pumped energy storage participating in peak and frequency regulation; The price model W corresponding to the variable bidding part freq for: in, represents the frequency modulation price, E cp It is the capacity involved in frequency modulation.

6. The method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration according to claim 4, characterized in that: The price model in the mature stage of the market is settled by participating in the ancillary service market, specifically: W=W com +W res Where W represents the ancillary service market revenue; W com and W res denote the frequency regulation and reserve auxiliary market revenues respectively; Among them, D t , and represents the frequency modulation mileage, the winning frequency modulation capacity and the frequency modulation mileage price in period t respectively; B cp is the frequency regulation capacity price; K and T are the comprehensive frequency regulation index and the metering period respectively; in: and They represent the winning bid and calling of spare capacity at time t, represents the spot market electricity price; B res is the spare capacity price.

7. The method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration according to claim 4, characterized in that: The cost diversion strategy in the initial stage of the market is to divert the cost to the user side based on a two-part electricity price.

8. The method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration according to claim 4, characterized in that: The mid-term cost management strategy model for the market is: Among them: F i and W i fix They represent the on-grid transaction power and fixed income sharing costs borne by the power generation entity i; W c fix and F c They represent the fixed cost and electricity consumption of user c respectively; η1 is the proportion of fixed income to shared expenses.

9. The method for establishing a cost diversion strategy for a pumped storage power station taking the market into consideration according to claim 4, characterized in that: The cost diversion strategy model for the mature market stage is: R c =(1-η2)WF c Where: R i represents the auxiliary service cost borne by the power generation entity i; R total and R c They represent the total ancillary service costs and the ancillary service share costs on the user side respectively; η2 is the ancillary service share ratio on the power generation side.

Images