Multi-provincial benefit sharing-oriented pumped storage power station peak shaving power optimization method

Abstract

The application belongs to the technical field of water conservancy and power engineering, and specifically discloses a pumped storage power station peak regulation power optimization method for multi-provincial benefit sharing, which comprises the following steps: obtaining the expected pumping power and the expected power generation power of each province to the pumped storage power station; checking the expected pumping power and the expected power generation power in combination with the physical constraints of the pumped storage power station to obtain the actual pumping power and the actual power generation power of each province; determining the residual load and the unallocated benefit power of each province according to the actual pumping power and the actual power generation power; and determining the peak regulation power of the pumped storage power station when the residual load fluctuation variance of each province meets the preset condition in combination with the residual load and the unallocated benefit power. The application constructs a benefit power provincial independent reporting and checking mechanism, and takes into account the provincial peak regulation willingness and the power station operation constraints.

Description

Technical Field

[0001] This invention belongs to the field of water conservancy and hydropower engineering technology, and specifically discloses a method for optimizing peak-shaving power of pumped storage power stations for multi-province benefit sharing. Background Technology

[0002] Pumped storage, as the most mature and economically efficient energy storage technology with the best life-cycle performance, plays a crucial role in new power systems due to its large capacity and long-cycle regulation advantages. It effectively alleviates the dual pressures of supply and consumption brought about by large-scale renewable energy grid integration. However, with the continuous increase in the penetration rate of new energy sources, relying solely on intra-provincial balancing is no longer sufficient to meet development needs, given the limitations of provincial regulation resources and consumption capacity. There is an urgent need to utilize inter-provincial transmission lines to break down regional barriers and achieve the sharing and optimized allocation of pumped storage regulation resources on a larger scale.

[0003] Existing inter-provincial peak-shaving resource sharing primarily employs centralized optimization methods, typically transforming the peak-shaving needs of multiple provinces into a weighted multi-objective optimization problem. While this method effectively reduces the computational complexity of large-scale resource allocation, weight settings often rely on subjective experience, making it difficult to accurately reflect the actual urgency of each province's peak-shaving needs. This easily leads to mismatches between intra-provincial peak-shaving needs and resource allocation results, thereby diminishing the actual value of flexible adjustment resources. With the deepening of inter-provincial medium- and long-term market construction, the dispatching model of grid-dispatched power sources is gradually shifting from "unified coordination by the dispatch center" to "independent decision-making and reporting by each province." As independent stakeholders, each province tends to maximize its own benefits by optimizing its reporting strategies. In this context, traditional centralized optimization methods are no longer suitable for the market environment of multi-stakeholder non-cooperative game theory, and a decentralized collaborative method that can fully reflect the independent autonomy of each province is urgently needed.

[0004] Unlike conventional cascade hydropower, pumped storage power stations are constrained by upstream and downstream reservoir capacity, exhibiting a significant "pump-and-charge coupling" characteristic. Particularly for daily-regulating pumped storage power stations, the dispatching process must strictly adhere to intraday water balance and the constraints of beginning and end water level connections. Under a multi-province cost-sharing model, each province enjoys corresponding regulatory rights based on its cost-sharing ratio. Therefore, when concurrent dispatch demands from multiple provinces exceed the physical regulation and transmission limits of the power station and its interconnection lines, a fair verification method must be established to ensure smooth execution on the physical side of the pumped storage power station while also considering the fairness of the rights and interests of each province on the market side. Summary of the Invention

[0005] The purpose of this invention is to provide a method for optimizing peak-shaving power of pumped storage power stations for multi-province benefit sharing, in order to solve the technical problem that existing methods for optimizing peak-shaving power of pumped storage power stations for multi-province benefit sharing have difficulty in simultaneously taking into account the smooth implementation of the pumped storage power station on the physical side and the rights and interests of each province on the market side.

[0006] This invention provides a method for optimizing peak-shaving power generation in pumped-storage power stations for multi-province benefit-sharing, comprising:

[0007] Obtain the expected pumping power and expected power generation of pumped storage power stations for each province;

[0008] The expected pumping power and the expected power generation are verified by combining the physical constraints of the pumped storage power station to obtain the actual pumping power and the actual power generation of each province.

[0009] Based on the actual pumping power and the actual power generation, determine the remaining load and remaining unallocated equity power of each province;

[0010] Based on the remaining load and the remaining unallocated equity power, the peak-shaving power of the pumped storage power station is determined so that the variance of the remaining load fluctuation in each province meets the preset conditions.

[0011] Preferably, the expected pumping power and the expected power generation are checked in conjunction with the physical constraints of the pumped storage power station, specifically as follows:

[0012] The expected pumping power and the expected power generation are checked in the first round based on the output of the pumped storage power station.

[0013] A second round of verification is conducted based on the reservoir water volume to determine the expected pumping power and expected power generation obtained in the first round of verification.

[0014] A third round of verification is conducted based on the transmission capacity of the tie line to determine the expected pumping power and expected power generation obtained in the second round of verification.

[0015] Preferably, the expected pumping power and the expected power generation are checked in the first round based on the output of the pumped storage power station, specifically as follows:

[0016] The expected total pumping power for all provinces is determined based on the expected pumping power for each province.

[0017] Based on the expected total pumping power and the maximum pumpable capacity of the pumped storage power station, the expected pumping power is verified, and the expected power generation is verified based on the verified expected pumping power.

[0018] The total expected power generation of all provinces after verification is determined based on the verified expected power generation of each province.

[0019] Based on the verified expected total power generation and the maximum power generation capacity of the pumped storage power station, the expected power generation is verified again, and the expected pumping power is verified again based on the verified expected power generation.

[0020] Preferably, the expected pumping power is verified based on the expected total pumping power and the maximum pumpable capacity of the pumped storage power station, specifically as follows:

[0021] Determine whether the expected total pumping power exceeds the maximum pumpable capacity of the pumped storage power station. If so, reduce the expected pumping power of each province during the over-limit period proportionally.

[0022] Preferably, the expected power generation is verified based on the verified expected pumping power, specifically as follows:

[0023] The expected total pumping power after verification for each province is determined based on the expected pumping power after verification for each province.

[0024] The expected power generation is verified based on the total expected pumping power after verification and the pumping-to-generation conversion coefficient of the pumped storage power station.

[0025] Preferably, a second round of verification is conducted based on the reservoir water volume to determine the expected pumping power and expected power generation obtained from the first round of verification. Specifically:

[0026] The reservoir operating water level is determined based on the expected pumping power and expected power generation obtained from the first round of verification.

[0027] Based on the relationship between the reservoir's operating water level and its highest and dead water levels, the expected pumping power and expected power generation obtained from the first round of verification are checked.

[0028] Preferably, a third round of verification is performed on the expected pumping power and expected power generation obtained from the second round of verification based on the transmission capacity of the tie line, specifically as follows:

[0029] Determine whether the interconnection lines in each province can meet the expected pumping power or expected power generation obtained after the second round of verification. If not, reduce the expected pumping power and expected power generation obtained after the second round of verification proportionally.

[0030] Preferably, the remaining load and remaining unallocated electricity rights of each province are determined based on the actual pumping power and actual power generation, specifically as follows:

[0031] The equivalent load for each province is determined based on the difference between the total load and the output of new energy sources in the corresponding province.

[0032] The remaining load for each province is determined based on the equivalent load, actual pumping power, and actual power generation.

[0033] The remaining unallocated equity electricity for each province is determined based on the initial allocation of equity electricity, the actual pumping power, and the actual power generation.

[0034] Preferably, by combining the remaining load and the remaining unallocated equity power, the peak-shaving power of the pumped storage power station is determined so that the variance of the remaining load fluctuation in each province meets the preset conditions, specifically as follows:

[0035] Determine the average remaining load across all provinces;

[0036] Based on the remaining load of each province and the average value of the remaining load, the peak-shaving power of the pumped storage power station is determined to minimize the variance of the remaining load fluctuation in each province.

[0037] Preferably, when determining the peak-shaving power of the pumped storage power station that minimizes the variance of the remaining load fluctuation in each province, the constraints of the pumped storage power station include reservoir water balance constraints, reservoir capacity constraints, power generation and pumping constraints, equity power constraints, and tie-line transmission constraints.

[0038] The method for optimizing peak-shaving power generation in pumped storage power stations for multi-province benefit sharing, as proposed in this invention, has the following advantages compared to existing technologies:

[0039] This invention presents a method for optimizing peak-shaving power capacity of pumped storage power stations for multi-province benefit sharing. It establishes a mechanism for independent provincial declaration and cyclical adjustment of benefit-sharing power capacity. Following the principle of decentralized coordination, each province formulates its own pumping and power generation declaration plan based on its load. The regional trading center then uniformly reduces and redistributes excess power declarations, balancing provincial peak-shaving intentions with power station operational constraints.

[0040] This invention proposes a contract curve verification strategy that balances fairness and physical constraints. A proportional reduction method is designed to handle over-limit electricity generation, maintaining the energy conversion coupling relationship between the extraction and generation sides while strictly adhering to the principle of equal rights between provinces, thus ensuring the consistency of reservoir water levels at the beginning and end of the day.

[0041] This invention reveals the mechanism by which the reservoir's initial regulating water level affects the contract fulfillment rate of equity-based electricity generation. It quantifies the coupling mechanism between the initial regulating water level of pumped storage and the inter-provincial allocation of equity-based pumped power generation, and provides recommendations for suitable reservoir initial regulating water levels to ensure the rigid fulfillment of equity-based pumped power generation. Attached Figure Description

[0042] Figure 1 This is a flowchart of a method for optimizing peak-shaving power generation in pumped storage power stations for multi-province benefit sharing, as described in an embodiment of the present invention.

[0043] Figure 2 This is a schematic diagram of the peak-shaving power cyclic allocation process in an embodiment of the present invention.

[0044] Figure 3 This is a flowchart illustrating the sequential verification process for a multi-province shared pumped storage power station, as described in an embodiment of the present invention.

[0045] Figure 4 This is a schematic diagram illustrating the proportional reduction of shared pumped storage power stations across multiple provinces, as per an embodiment of the present invention.

[0046] Figure 5 (a) is a diagram of the initial application process for pumped storage power output in Shaanxi Province in an embodiment of the present invention (Scenario 1); (b) is a diagram of the initial application process for pumped storage power output in Gansu Province in an embodiment of the present invention (Scenario 1); (c) is a diagram of the initial application process for pumped storage power output in Qinghai Province in an embodiment of the present invention (Scenario 1); and (d) is a diagram of the initial application process for pumped storage power output in Ningxia Province in an embodiment of the present invention (Scenario 1).

[0047] Figure 6 (a) is a summary diagram of the initial declared power output of each province in the embodiment of the present invention (Scenario 1); (b) is a diagram of the over-limit situation of the upper reservoir when the pumped storage power station operates according to the initial declared power output of each province in the embodiment of the present invention (Scenario 1); (c) is a diagram of the over-limit situation of the lower reservoir when the pumped storage power station operates according to the initial declared power output of each province in the embodiment of the present invention (Scenario 1).

[0048] Figure 7 (a) is a process diagram of the application and power verification process for the extraction of rights in Shaanxi Province in an embodiment of the present invention (Scenario 1, first iteration); (b) is a process diagram of the application and power verification process for the extraction of rights in Gansu Province in an embodiment of the present invention (Scenario 1, first iteration); (c) is a process diagram of the application and power verification process for the extraction of rights in Qinghai Province in an embodiment of the present invention (Scenario 1, first iteration); and (d) is a process diagram of the application and power verification process for the extraction of rights in Ningxia Province in an embodiment of the present invention (Scenario 1, first iteration).

[0049] Figure 8 (a) is a diagram of the application and power verification process for the extraction of rights in Shaanxi Province in an embodiment of the present invention (Scenario 1, second iteration); (b) is a diagram of the application and power verification process for the extraction of rights in Gansu Province in an embodiment of the present invention (Scenario 1, second iteration); (c) is a diagram of the application and power verification process for the extraction of rights in Qinghai Province in an embodiment of the present invention (Scenario 1, second iteration); and (d) is a diagram of the application and power verification process for the extraction of rights in Ningxia Province in an embodiment of the present invention (Scenario 1, second iteration).

[0050] Figure 9 (a) is a diagram of the application and power verification process for the rights and interests extraction in Shaanxi Province in an embodiment of the present invention (Scenario 1, third iteration); (b) is a diagram of the application and power verification process for the rights and interests extraction in Gansu Province in an embodiment of the present invention (Scenario 1, third iteration); (c) is a diagram of the application and power verification process for the rights and interests extraction in Qinghai Province in an embodiment of the present invention (Scenario 1, third iteration); and (d) is a diagram of the application and power verification process for the rights and interests extraction in Ningxia Province in an embodiment of the present invention (Scenario 1, third iteration).

[0051] Figure 10 (a) is a flowchart of the application and electricity verification process for the Shaanxi rights and interests extraction process in an embodiment of the present invention (Scenario 1, second iteration); (b) is a flowchart of the application and electricity verification process for the Gansu rights and interests extraction process in an embodiment of the present invention (Scenario 1, second iteration); (c) is a flowchart of the application and electricity verification process for the Qinghai rights and interests extraction process in an embodiment of the present invention (Scenario 1, second iteration); and (d) is a flowchart of the application and electricity verification process for the Ningxia rights and interests extraction process in an embodiment of the present invention (Scenario 1, second iteration).

[0052] Figure 11 (a) is a diagram of the first iteration of the application and verification process for the rights and interests extraction process in Shaanxi Province according to an embodiment of the present invention (Scenario 2); (b) is a diagram of the second iteration of the application and verification process for the rights and interests extraction process in Shaanxi Province according to an embodiment of the present invention (Scenario 2); (c) is a diagram of the third iteration of the application and verification process for the rights and interests extraction process in Shaanxi Province according to an embodiment of the present invention (Scenario 2); and (d) is a diagram of the fourth iteration of the application and verification process for the rights and interests extraction process in Shaanxi Province according to an embodiment of the present invention (Scenario 2).

[0053] Figure 12 (a) is a summary diagram of the output of the pumped storage power station in the embodiment of the present invention (Scenario 1, after verification); (b) is a diagram of the water level change of the upper reservoir when the pumped storage power station is output in the embodiment of the present invention (Scenario 1, after verification); (c) is a diagram of the water level change of the lower reservoir when the pumped storage power station is output in the embodiment of the present invention (Scenario 1, after verification).

[0054] Figure 13 This is the result of a sensitivity analysis of the impact of the reservoir's initial water level on the allocation of equity-based electricity in an embodiment of the present invention. Detailed Implementation

[0055] In the following description, specific details such as particular system architectures and techniques are set forth for illustrative purposes and not for limitation, in order to provide a thorough understanding of the embodiments of the invention. However, those skilled in the art will understand that the invention can be implemented in other embodiments without these specific details. In other instances, detailed descriptions of well-known systems, apparatuses, circuits, and methods are omitted so as not to obscure the description of the invention with unnecessary detail.

[0056] This invention proposes a decentralized coordination framework for pumped storage power stations with shared benefits across multiple provinces. This framework includes a benefit-sharing power allocation mechanism that integrates independent decision-making by each province with multi-round verification by a regional trading center. It allows each province to independently declare its power output based on its own peak-shaving needs, accurately reflecting the peak-shaving intentions of each participating province. Simultaneously, a cyclical verification method effectively ensures the full allocation and equal rights of benefit-sharing power to each province. The ultimately recommended starting water levels for upper and lower reservoirs provide theoretical guidance for the practical operation of pumped storage power stations with shared benefits across multiple provinces.

[0057] The present invention provides an optimization method for peak-shaving power of pumped storage power stations based on the above-mentioned decentralized coordination framework and oriented towards multi-province benefit sharing. Figures 1 to 13 As shown, it includes:

[0058] Step 1: Obtain the expected pumping power and expected power generation of pumped storage power stations for each province.

[0059] To effectively coordinate the peak-shaving demands of various provinces and ensure the safe and stable operation of the regional power grid, this embodiment of the invention constructs a multi-stage, iterative multi-province allocation mechanism for the equity electricity of pumped storage power stations, which mainly includes three stages: independent application by provinces, regional aggregation and verification, and cyclical settlement of equity.

[0060] The independent declaration by provinces is as follows: Each province, with the goal of minimizing the fluctuation of the remaining load after deducting renewable energy, and in accordance with the total equity power constraint, independently formulates and declares its expected intraday pumping and power generation curves. The intraday pumping power curve for each province represents the expected pumping power of the pumped storage power station for each province; the intraday power generation curve for each province represents the expected power generation of the pumped storage power station for each province.

[0061] Step 2: Verify the expected pumping power and expected power generation based on the physical constraints of the pumped storage power station to obtain the actual pumping power and actual power generation for each province.

[0062] Step 2 of this embodiment is essentially a regional aggregation verification, that is, the regional trading center summarizes and aggregates the expected pumping power and expected power generation of each province to form the pre-planned output process of the pumped storage power station, and uses it to verify feasibility.

[0063] To ensure the smooth physical execution of the rights and interests allocation process after aggregation in each province by pumped-storage hydroelectric power stations, rigorous verification is essential. This invention employs a sequential verification mechanism that consistently adheres to the principle of "proportional reduction" for fairness and sequentially addresses three key physical constraints: power station output, reservoir water volume, and interconnection line transmission capacity. The verification process is as follows: Figure 3 As shown, step 2 above specifically involves:

[0064] Step 2.1: Conduct the first round of verification of the expected pumping power and expected power generation based on the output of the pumped storage power station, such as... Figure 4 As shown.

[0065] The first round of verification aims to ensure that the total pumping power and total power generation in each province do not exceed the unit capacity limits of pumped storage power stations. The first round of verification consists of two steps: proportionally reducing power generation exceeding limits during the pumping process and proportionally correcting the adjusted power generation. After the pumping process verification is completed, the same verification process will be performed on the power generation process.

[0066] First, the pumping process is checked, specifically including steps 2.1.1 and 2.1.2 as follows.

[0067] Step 2.1.1: Determine the total expected pumping power for all provinces based on the expected pumping power of each province.

[0068] Step 2.1.2: Based on the expected total pumping power and the maximum pumpable capacity of the pumped storage power station, verify the expected pumping power, and then verify the expected power generation based on the verified expected pumping power.

[0069] Specifically, the expected pumping power is verified based on the expected total pumping power and the maximum pumpable capacity of the pumped storage power station, as follows:

[0070] Determine whether the expected total pumping power exceeds the maximum pumpable capacity of the pumped storage power station. If not, the verification is passed; if so, there is a constraint exceeding the limit. In accordance with the principle of fairness, the expected pumping power declared by each province during the period exceeding the limit is reduced proportionally until the capacity constraint is met, and the verified expected pumping power is obtained.

[0071] Furthermore, the expected power generation is verified based on the verified expected pumping power, specifically as follows:

[0072] The expected total pumping power of each province is determined based on the verified expected pumping power of each province; then the expected power generation is verified based on the verified expected total pumping power and the pumping-to-generation conversion coefficient of the pumped storage power station.

[0073] Specifically, the expected power generation is verified based on the verified expected total pumping power and the pumping-to-generation conversion coefficient of the pumped storage power station, as follows:

[0074] The total power generation is calculated by converting the expected total pumping power after verification with the pumping conversion factor of the pumped storage power station. The reduction ratio of the expected power generation for all power generation periods is calculated based on the converted total power generation. Then, the expected power generation for each period is reduced proportionally to obtain the verified expected power generation.

[0075] After the pumping process is verified, the power generation process is verified, as detailed in steps 2.1.3 and 2.1.4.

[0076] Step 2.1.3: Determine the total expected power generation of all provinces after verification based on the expected power generation of each province after verification.

[0077] Step 2.1.4: Based on the verified expected total power generation and the maximum power generation capacity of the pumped storage power station, verify the expected power generation again, and then verify the expected pumping power again based on the verified expected power generation. The verified expected power generation and the verified expected pumping power are the results of the first round of verification.

[0078] Specifically, the expected power generation is re-verified based on the verified expected total power generation and the maximum power generation capacity of the pumped storage power station, as follows:

[0079] Determine whether the expected total power generation after verification exceeds the maximum power generation capacity of the pumped storage power station. If not, the verification is passed. If so, there is a constraint exceeding the limit. In accordance with the principle of fairness, the expected power generation declared by each province during the period exceeding the limit is reduced proportionally until the capacity constraint is met, and the expected power generation after verification is obtained.

[0080] Furthermore, the expected pumping power is further verified based on the re-verified expected power generation, specifically as follows:

[0081] The expected total power generation after re-verification is determined based on the expected power generation after re-verification; then the expected pumping power is re-verified based on the expected total power generation after re-verification and the pumping conversion coefficient of the pumped storage power station.

[0082] Specifically, the expected pumping power is re-verified based on the expected total power generation after re-verification and the pumping-generation conversion coefficient of the pumped storage power station, as follows:

[0083] The total pumping power is calculated by converting the expected total power generation after re-verification with the pumping-generation conversion coefficient of the pumped storage power station. The reduction ratio of the expected pumping power for all pumping periods is calculated based on the converted total pumping power. Then, the expected pumping power for each period is reduced proportionally to obtain the expected pumping power after re-verification.

[0084] Step 2.1 of this embodiment of the invention strictly ensures that the total power curve after verification of each province does not exceed the capacity limit of the pumped storage power station at any time, while also maintaining the physical balance of the daily water pumping volume of the pumped storage power station, thus ensuring the consistency of reservoir operation on medium and long-term time scales.

[0085] Step 2.2: Based on the reservoir water volume, conduct a second round of verification of the expected pumping power and expected power generation obtained in the first round of verification.

[0086] In addition to power output verification, this embodiment of the invention performs reservoir water volume verification. The reservoir water volume verification aims to check whether the operation of the pumped storage power station can meet the adjustable water volume constraints of the upper and lower reservoirs.

[0087] Step 2.2 above specifically refers to:

[0088] Step 2.2.1: Determine the reservoir operating water level based on the expected total pumping power and expected total power generation obtained from the first round of verification.

[0089] According to the embodiments of the present invention, the expected total pumping power of all provinces can be obtained based on the expected pumping power of each province obtained in the first round of verification, and the expected total power generation of all provinces can be obtained based on the expected power generation of each province obtained in the first round of verification.

[0090] Step 2.2.2: Based on the relationship between the reservoir's operating water level, the highest water level, and the dead water level, verify the expected pumping power and expected power generation obtained from the first round of verification.

[0091] The embodiments of the present invention first simulate the reservoir water level operation trajectory throughout the entire cycle based on the pumping power generation process, and then determine whether the reservoir water volume needs to be checked based on the water level exceeding the limit.

[0092] If the water level of the upper reservoir exceeds the maximum water level, calculate the total "excess water volume" and distribute its equivalent "energy surplus" to all pumping and power generation periods in the same proportion, and reduce the expected pumping power and expected power generation power obtained from the first round of verification in proportion.

[0093] Similarly, if the water level of the upper reservoir is lower than the dead water level, the "water deficit" is calculated, and its equivalent "energy deficit" is allocated to all pumping and power generation periods in the same proportion. The expected pumping power and expected power generation obtained from the first round of verification are reduced proportionally.

[0094] The verification process for the lower reservoir is the same as that for the upper reservoir, but the criteria for adjustment are reversed. Specifically, if the water level of the lower reservoir exceeds the maximum water level, the total "exceedance water volume" is calculated, and its equivalent "energy surplus" is allocated to all pumping and power generation periods in the same proportion. The expected pumping power and expected power generation obtained from the first round of verification are then reduced proportionally.

[0095] Similarly, if the water level in the lower reservoir is lower than the dead water level, the "water deficit" is calculated, and its equivalent "energy deficit" is allocated to all pumping and power generation periods in the same proportion. The expected pumping power and expected power generation obtained in the first round of verification are reduced proportionally.

[0096] Step 2.3: Based on the transmission capacity of the tie line, conduct a third round of verification on the expected pumping power and expected power generation obtained from the second round of verification. Specifically:

[0097] After the second round of verification, it is determined whether the interconnection lines of each province can meet the expected pumping power or expected power generation. If not, the expected pumping power or expected power generation obtained from the second round of verification will be reduced proportionally.

[0098] This invention embodiment performs a tie-line safety check on the expected pumping power or expected power generation after the second round of verification. This stage primarily considers whether the remaining transmission capacity of the tie-line between each province and the pumped storage power station (i.e., the available capacity after deducting existing transmission plans) can meet the transaction plans between the pumped storage power station and the participating provinces. When the power flow of the tie-line exceeds the safety limit after adding pumping or power generation output during a certain period, the declared expected pumping power or expected power generation of all provinces using the tie-line for transmission during that period will be proportionally reduced according to the declared ratio until the power flow of the tie-line meets the safety constraints.

[0099] First, the pumping process is verified, which includes the following steps:

[0100] Step 2.3.1: Based on the expected pumping power of each province after the second round of verification and the remaining transmission capacity of the interconnection lines between each province and the pumped storage power station, verify the expected pumping power, and verify the expected power generation based on the verified expected pumping power.

[0101] Specifically, the expected pumping power is verified based on the expected pumping power of each province after the second round of verification and the remaining transmission capacity of the interconnection lines between each province and the pumped storage power station.

[0102] Determine whether the expected pumping power of each province after the second round of verification exceeds the remaining transmission capacity of the interconnection line between each province and the pumped storage power station. If not, the verification is passed; if so, there is a constraint exceeding the limit. In accordance with the principle of fairness, the expected pumping power of each province during the period of exceeding the limit after the second round of verification is reduced by a proportional reduction method until the remaining transmission capacity constraint is met, and the verified expected pumping power is obtained.

[0103] Furthermore, the expected power generation is verified based on the verified expected pumping power, specifically as follows:

[0104] Based on the verified expected pumping power of each province, the expected total pumping power is calculated. The expected total power generation of each province is then converted with the pumping-generation conversion coefficient of the pumped storage power station. Based on the expected total power generation, the reduction ratio of the expected power generation for each province during all power generation periods is calculated. Then, the expected power generation for each province during each period is reduced proportionally to obtain the verified expected power generation for each province.

[0105] After verifying the pumping process, the power generation process is verified, as detailed in step 2.3.2. Step 2.3.2: Based on the verified expected power generation of each province and the remaining transmission capacity of the interconnection lines between each province and the pumped storage power station, the expected power generation is verified again. Then, based on the verified expected power generation of each province, the expected pumping power of each province is verified again. The verified expected power generation and the verified expected pumping power are the results of the third round of verification.

[0106] Specifically, based on the expected power generation of each province after verification and the remaining transmission capacity of the interconnection lines between each province and the pumped storage power station, the expected power generation is verified again, as follows:

[0107] Determine whether the expected power generation of each province after verification exceeds the remaining transmission capacity of the interconnection line between each province and the pumped storage power station. If not, the verification is passed; if so, there is a constraint exceeding the limit. In accordance with the principle of fairness, the expected power generation of each province during the period of exceeding the limit after the second round of verification is reduced by a proportional reduction method until the remaining transmission capacity constraint is met, and the expected power generation after the second verification is obtained.

[0108] Furthermore, the expected pumping power of each province is further verified based on the expected power generation after the previous verification. Specifically:

[0109] The expected total power generation is calculated based on the expected power generation of each province after re-verification. The expected total pumping power of each province is then converted with the pumping-generation conversion factor of the pumped storage power station. Based on the expected total pumping power of each province, the reduction ratio of the expected pumping power for all pumping periods in each province is calculated. Then, the expected pumping power of each province in each period is reduced proportionally to obtain the expected pumping power of each province after re-verification.

[0110] The expected pumping power obtained from the third round of verification in this embodiment of the invention is the actual pumping power, and the expected power generation obtained from the third round of verification is the actual power generation. The actual pumping power and the actual power generation are locked to the "tradeable power curve" of each province.

[0111] Step 3: Determine the remaining load and remaining unallocated electricity for each province based on the actual pumping power and actual power generation.

[0112] Specifically, based on the actual pumping power and actual power generation, the remaining load of each province is determined, which involves determining the equivalent load of each province. The equivalent load is determined based on the difference between the total load and the output of new energy sources in the corresponding province; then, based on the equivalent load... The actual pumping power and actual power generation power determine the remaining load of each province. .

[0113] The remaining unallocated equity electricity for each province is determined based on the actual pumping power and actual power generation. Specifically, the remaining unallocated equity electricity for each province is determined based on the initial equity electricity allocation, the actual pumping power, and the actual power generation.

[0114] Step 4: Combine with residual load Based on the remaining unallocated equity-based electricity, the peak-shaving electricity capacity of pumped storage power stations is determined to ensure that the variance of the remaining load fluctuation in each province meets the preset conditions, specifically as follows:

[0115] Step 4.1: Determine the average remaining load for all provinces;

[0116] Step 4.2: Based on the remaining load and average remaining load of each province, determine the peak-shaving power of the pumped storage power station that minimizes the variance of the remaining load fluctuation in each province.

[0117] In this embodiment of the invention, steps 3 and 4 are implemented using a short-term peak-shaving scheduling model for pumped storage power stations.

[0118] First, determine the specific objective function of the short-term peak-shaving scheduling model for pumped storage power stations.

[0119] From a mathematical perspective, the peak and valley filling demands of each power grid can be described by minimizing the fluctuation of the remaining load after deducting renewable energy from the grid load. The specific objective function is as follows:

[0120] (1)

[0121] In the formula, Indicates the rights and interests of the province The variance of the remaining load fluctuation, and =1, 2… , Indicates the number of provinces with rights; Provinces representing rights During the period The remaining load is obtained by deducting the output of new energy sources such as wind and solar power and pumped storage power stations from the total load, in MW; Indicates the rights and interests of the province Average remaining load, MW; Indicates the rights and interests of the province The equivalent load is obtained by subtracting the output of new energy sources from the total load, in MW; and These respectively represent pumped storage power stations and the provinces with rights and interests. During the period The signed medium- and long-term power generation contracts (actual power generation capacity) and pumping contracts (actual pumping capacity) amount to MW.

[0122] The operational constraints of the short-term peak-shaving dispatch model for pumped storage power stations in this embodiment of the invention mainly include reservoir water balance constraints, reservoir capacity constraints, power generation and pumping constraints, equity power constraints, and tie-line transmission constraints.

[0123] Reservoir water balance constraints:

[0124] (2)

[0125] In the formula, and These represent the upper and lower reservoirs during different time periods. The reservoir's water storage capacity is 10,000 m³. 3 ; and These represent the upper and lower reservoirs during different time periods. The reservoir's water storage capacity is 10,000 m³. 3 ; and These represent the time periods of the pumped storage power station. Pumping and power generation flow rate, m 3 / s; This represents a time interval, which is 1 hour in this case.

[0126] Reservoir capacity constraints:

[0127] (3)

[0128] (4)

[0129] (5)

[0130] In the formula, and These represent the minimum water storage capacity of the upper and lower reservoirs, in ten thousand cubic meters. 3 ; and These represent the maximum water storage capacity of the upper and lower reservoirs, in tens of thousands of cubic meters. 3 ; and These represent the water level-capacity curve function relationship between the upper and lower reservoirs, respectively. and These represent the water storage capacity of the upper reservoir at the beginning and end of the day, in ten thousand cubic meters. 3 .

[0131] Power generation and pumping constraints:

[0132] (6)

[0133] (7)

[0134] (8)

[0135] (9)

[0136] In the formula, and These represent the time periods of the pumped storage power station. The lower and upper limits of power generation, in MW; and These represent the time periods of the pumped storage power station. The lower and upper limits of pumping power, in MW; and These represent the time periods of the pumped storage power station. The relationship between power generation conversion and pumping power conversion; and The upper and lower reservoirs were respectively located during the following time periods. The reservoir water level, in meters (m); and The upper and lower reservoirs were respectively located during the following time periods. The reservoir water level, in meters (m); This indicates the time period of the pumped storage power station. The hydroelectric head or pumping head is obtained by the difference between the average water level of the upper reservoir and the average water level of the lower reservoir during the same period, in meters.

[0137] Electricity consumption constraints:

[0138] (10)

[0139] (11)

[0140] (12)

[0141] In the formula, Indicates province The percentage of electricity that is rightfully owned is determined by the percentage of capacity charges paid.

[0142] Tether transmission constraints:

[0143] (13)

[0144] In the formula, This indicates the relationship between pumped storage power stations and provinces. Inter-connection line section during time period Transmitted power, MW; Indicates with provinces The maximum remaining transmission capacity of the inter-connection line section, MW.

[0145] In this embodiment of the invention, the nonlinear constraints of the short-term peak-shaving dispatch model for pumped storage power stations, such as the water level-storage capacity curve, are transformed using SOS2 piecewise linear functions. The power generation function and the pumping power function are solved separately using triangulation techniques; specific details are not elaborated here. After linearizing the nonlinear constraints in the pumped storage power station's constraints, a mixed-integer linear programming (MILP) model is formed and solved using the GUROBI solver to obtain the recommended suitable range of initial daily peak-shaving water levels for the pumped storage power station.

[0146] After steps 1 to 4 of this embodiment of the invention are completed, a cyclical settlement of rights and interests is carried out. Specifically, the trading center compiles statistics on the usage of rights and interests electricity after the first round of verification. If there are still remaining rights and interests electricity that have not been allocated, the next round of rolling allocation and verification procedure is initiated based on the fixed electricity curve of the previous round. This process is repeated cyclically until all rights and interests electricity are allocated or the pumped storage power station has no adjustment margin.

[0147] This invention proposes a decentralized coordination framework for the shared rights and interests of pumped storage power stations across multiple provinces. Based on the principle of "shared rights and interests, equal access," this framework constructs a rights and interests allocation mechanism that integrates independent decision-making by each province with multi-round verification by the regional trading center, thereby achieving optimized allocation of pumped storage resources for flexible regulation.

[0148] The effectiveness of the method of the present invention will be described in detail below with more specific embodiments.

[0149] The research object of this invention is the Zhen'an pumped storage power station in Shaanxi Province, and the research area covers four northwestern provinces and autonomous regions: Shaanxi, Gansu, Qinghai, and Ningxia. The four provinces and autonomous regions share the capacity-based electricity tariff for pumped storage power stations at 70%, 11%, 11%, and 8% respectively, and therefore also enjoy a corresponding proportion of the electricity usage rights within the pumped storage power station's rights. This rights-based electricity usage consists of both the pumped water volume and the generated electricity from the pumped storage power station.

[0150] The specific parameters of the Zhen'an pumped storage power station according to an embodiment of the present invention are shown in Table 1.

[0151] Table 1 Characteristic parameters of pumped storage power stations

[0152]

[0153] To illustrate in detail the impact of different initial water levels on the allocation of pumped storage power, this embodiment of the invention sets up two reservoir initial water level scenarios, representing two typical operating conditions: restricted and unrestricted allocation of pumped storage power. Scenario 1 (restricted condition) is set as follows: the initial water level of the upper reservoir is 9.319 million m³. 3 The initial storage capacity of the lower reservoir is 13.8243 million cubic meters. 3Scenario 2 (Unrestricted Operating Conditions) is set as follows: Initial storage capacity of the upper warehouse is 9.225 million m³. 3 The initial storage capacity of the lower reservoir is 13.824 million cubic meters. 3 All other conditions are the same.

[0154] To focus on the issue of distributed coordination of peak-shaving power from pumped storage power stations, the embodiments of this invention also make the following three simplifying assumptions:

[0155] (1) Each province needs to control the daily percentage of its pumped storage electricity when enjoying the right to use the electricity.

[0156] (2) Considering that the over-limit verification principle of the transmission capacity of the tie line is the same as that of the power output verification of the power station, both of which reduce the power during the over-limit period proportionally, the present invention will not analyze it separately. It is assumed that the transmission section of the inter-provincial tie line always meets the requirements for pumped storage power transmission.

[0157] (3) The rights and interests of provinces are only subject to the rights and interests of pumped storage power stations, and are not subject to the rights and interests capacity restrictions.

[0158] In this embodiment of the invention, a typical day of scenario one is selected for analysis. The designed annual pumped power generation within the equity scope of the pumped storage power station is evenly distributed to each day of the year to obtain the total daily equity electricity of each province and autonomous region. Then, it is allocated to the equity provinces and autonomous regions according to the capacity charge payment ratio. Among them, the daily equity electricity allocated to Shaanxi, Gansu, Qinghai and Ningxia are 10571.92MWh, 1661.30MWh, 1661.30MWh and 1208.22MWh, respectively.

[0159] During the initial application, each participating province and autonomous region used its allocated electricity volume for the day as the available pumped storage regulation capacity. The scheduling objective was to minimize the fluctuation of the remaining load within the provincial system. Taking into account the generating capacity of pumped storage power stations and transmission constraints of tie lines, the application process for pumped storage regulation was calculated separately. The application results are shown below. Figure 5 At this time, the regulating power of pumped storage power stations is distributed during the periods when peak-shaving demand is most urgent within the province and autonomous region.

[0160] By summarizing the reported contributions from each participating province and autonomous region, the initial pumped storage dispatch process can be obtained (see...). Figure 6 It is clear that, after aggregation, the pumped storage power station's maximum pumping power reached 2753MW at midday, and its power generation reached 1973MW during the evening peak, both exceeding the station's installed capacity of 1400MW. Simultaneously, the water storage in the upper reservoir increased to 10.002 million m³ during the 60th time period. 3 This exceeds the maximum water storage capacity of the upper reservoir, which is 8.96 million cubic meters. 3 Therefore, it is necessary to reduce the declared contributions of each claiming province and autonomous region according to the principle of proportionality.

[0161] The process of proportionally reducing power plant output in the four provinces and autonomous regions is as follows: Figure 7 As shown in the figure. Analysis results indicate that provinces and autonomous regions generally tend to declare pumping demand during peak photovoltaic output (period 48) and power generation demand during peak evening load periods (period 80). This concentrated declaration in time leads to the most significant over-limiting of pumped storage power during these periods. Taking Shaanxi Province as an example, it declares the largest power during the pumping period and bears the largest corresponding reduction: the pumping power during period 48 is reduced from 1400MW to 704MW, and the power generation power during period 78 is reduced from 1400MW to 1114.9MW (see...). Figure 7 (a) In addition, in accordance with the power balance constraints of pumped storage power stations, when the pumping or power generation capacity of a certain province is restricted and reduced, the power on the opposite side must also be reduced proportionally throughout the entire time period according to the pumping and power generation efficiency conversion relationship, so as to ensure the physical feasibility of the power station operation.

[0162] For the power generation verification process triggered by reservoir water levels exceeding limits, a strategy of proportionally reducing the pumping / generating power of each claiming province throughout the entire time period will be adopted. In Scenario 1, if the claimable power generation of each province in the second round fails the water volume verification process, the output result after proportional reduction will be as follows: Figure 10 As shown, this adjustment process essentially involves scaling the output amplitude as a whole while keeping the shape of the declaration curves for each province unchanged.

[0163] The process of claiming and verifying the reduction of electricity rights in Shaanxi Province during multiple iterations under Scenario 2 is as follows: Figure 11 As shown in the figure. Analysis reveals that the allocation of equity-based power capacity in different rounds is always guided by meeting the critical peak-shaving needs within the system. With further iterations, the deviation between the verified output and the declared output gradually converges. When the two curves coincide, it signifies that the equity-based power capacity allocation is complete; otherwise, it means that the equity-based power capacity cannot be further allocated. Figure 8 and Figure 9 .

[0164] The final operation process of the pumped storage tank after verification is as follows: Figure 12 As shown in the figure, the power plant output and reservoir water level under the final dispatch scheme strictly meet the constraints of pumped storage operation. This verifies the effectiveness of the invention, namely, that while ensuring the peak-shaving needs of each province are met, a reasonable allocation of equity power within the pumped storage operation domain is achieved.

[0165] To further explore the profound impact of reservoir capacity constraints on the allocation of equity-based electricity, this invention conducted a year-round sensitivity analysis on the starting water levels of the upper and lower reservoirs. By statistically analyzing the number of days with "incomplete allocation" of equity-based electricity under different combinations of starting water levels and system load scenarios throughout the year, a mapping relationship between the starting water level and the number of allocation failures was constructed, such as... Figure 13As shown in the figure. The results indicate that under most preset starting water level scenarios, the obstruction of equity power allocation is common, and the frequency of incomplete allocation remains at a high level. The obstruction is only alleviated when the upper reservoir is at a low water level and the lower reservoir is at a high water level.

[0166] Combination Figure 5 The application characteristics across various provinces reveal that pumped-storage power stations generally exhibit a typical operating pattern of "pumping water during midday to fill valleys and releasing water at night to regulate peak flows." Under this pattern, the water level in the upper reservoir primarily undergoes a diurnal variation of "rising first and then falling," while the lower reservoir shows the opposite trend. This means that if the initial water level in the upper reservoir is too high, there is a risk of reservoir overflow during pumping periods; conversely, if the initial water level in the lower reservoir is too low, the available water supply for pumping is limited. These physical constraints result in limited effective regulation capacity of pumped-storage power stations under certain initial water level conditions, leading to a lower verified electricity output than the equity-based output.

[0167] Through a comprehensive search, the optimal starting water level range for the Zhen'an pumped storage power station was found to be 1372-1378m for the upper reservoir and 934-941m for the lower reservoir. Within this range, the number of days without allocated equity electricity is significantly lower than other water level combinations, indicating that the water level constraint is relaxed or even eliminated. Therefore, it is recommended that the Zhen'an pumped storage power station maintain the reservoir's starting water level within this range as much as possible during daily operation to fully realize the flexible regulation value of the pumped storage power station.

[0168] This invention presents a method for optimizing peak-shaving power capacity of pumped storage power stations for multi-province benefit sharing. It establishes a mechanism for independent provincial declaration and cyclical adjustment of benefit-sharing power capacity. Following the principle of decentralized coordination, each province formulates its own pumping and power generation declaration plan based on its load. The regional trading center then uniformly reduces and redistributes excess power declarations, balancing provincial peak-shaving intentions with power station operational constraints.

[0169] This invention proposes a contract curve verification strategy that balances fairness and physical constraints. A proportional reduction method is designed to handle over-limit electricity generation, maintaining the energy conversion coupling relationship between the extraction and generation sides while strictly adhering to the principle of equal rights between provinces, thus ensuring the consistency of reservoir water levels at the beginning and end of the day.

[0170] This invention reveals the mechanism by which the reservoir's initial regulating water level affects the contract fulfillment rate of equity-based electricity generation. It quantifies the coupling mechanism between the initial regulating water level of pumped storage and the inter-provincial allocation of equity-based pumped power generation, and provides recommendations for suitable reservoir initial regulating water levels to ensure the rigid fulfillment of equity-based pumped power generation.

[0171] The above descriptions are merely a few embodiments of the present invention and are not intended to limit the present invention in any way. Although the present invention has been disclosed above with reference to preferred embodiments, it is not intended to limit the present invention. Any modifications or alterations made by those skilled in the art without departing from the scope of the technical solution of the present invention using the disclosed technical content are equivalent to equivalent implementation cases and fall within the scope of the technical solution.

Claims

1. A method for optimizing peak-shaving power generation in pumped-storage power stations with shared benefits across multiple provinces, characterized in that: include: Obtain the expected pumping power and expected power generation of pumped storage power stations for each province; The expected pumping power and expected power generation are verified by considering the physical constraints of the pumped storage power station to obtain the actual pumping power and actual power generation for each province, specifically: The first round of verification is conducted based on the output of the pumped storage power station to determine the expected pumping power and the expected power generation. Specifically: The expected total pumping power for all provinces is determined based on the expected pumping power for each province. Based on the expected total pumping power and the maximum pumpable capacity of the pumped storage power station, the expected pumping power is verified, and the expected power generation is verified based on the verified expected pumping power. Specifically, it is determined whether the expected total pumping power exceeds the maximum pumpable capacity of the pumped storage power station. If so, the expected pumping power of each province during the over-limit period is reduced proportionally. The verified expected total pumping power of the corresponding province is determined based on the verified expected pumping power of each province. The expected power generation is verified based on the verified expected total pumping power and the pumping-to-generation conversion coefficient of the pumped storage power station. The total expected power generation of all provinces after verification is determined based on the verified expected power generation of each province. Based on the verified expected total power generation and the maximum power generation capacity of the pumped storage power station, the expected power generation is verified again, and the expected pumping power is verified again based on the verified expected power generation. A second round of verification is conducted based on the reservoir's water volume, using the expected pumping power and expected power generated from the first round of verification. Specifically, the reservoir's operating water level is determined based on the expected pumping power and expected power generated from the first round of verification; and the expected pumping power and expected power generated from the first round of verification are verified based on the relationship between the reservoir's operating water level and the highest water level and dead water level. Based on the transmission capacity of the tie line, a third round of verification is conducted on the expected pumping power and expected power generation obtained in the second round of verification to obtain the actual pumping power and actual power generation of each province. Specifically, it is determined whether the tie line of each province can meet the expected pumping power or expected power generation obtained after the second round of verification. If not, the expected pumping power and expected power generation obtained in the second round of verification are reduced proportionally. Based on the actual pumping power and the actual power generation, determine the remaining load and remaining unallocated equity power of each province; Based on the remaining load and the remaining unallocated equity power, the peak-shaving power of the pumped storage power station is determined so that the variance of the remaining load fluctuation in each province meets the preset conditions.

2. The method for optimizing peak-shaving power of pumped storage power stations for multi-province benefit sharing as described in claim 1, characterized in that, Based on the actual pumping capacity and actual power generation capacity, the remaining load and remaining unallocated electricity rights of each province are determined as follows: The equivalent load for each province is determined based on the difference between the total load and the output of new energy sources in the corresponding province. The remaining load for each province is determined based on the equivalent load, actual pumping power, and actual power generation. The remaining unallocated equity electricity for each province is determined based on the initial allocation of equity electricity, the actual pumping power, and the actual power generation.

3. The method for optimizing peak-shaving power of pumped storage power stations for multi-province benefit sharing as described in claim 1, characterized in that, Based on the remaining load and the remaining unallocated equity power, the peak-shaving power of the pumped storage power station is determined to ensure that the variance of the remaining load fluctuation in each province meets the preset conditions, specifically as follows: Determine the average remaining load across all provinces; Based on the remaining load of each province and the average value of the remaining load, the peak-shaving power of the pumped storage power station is determined to minimize the variance of the remaining load fluctuation in each province.

4. The method for optimizing peak-shaving power of pumped storage power stations for multi-province benefit sharing as described in claim 3, characterized in that, When determining the peak-shaving power of the pumped storage power station that minimizes the variance of the remaining load fluctuation in each province, the constraints of the pumped storage power station include reservoir water balance constraints, reservoir capacity constraints, power generation and pumping constraints, equity power constraints, and tie-line transmission constraints.

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