A control method and system for pumping and forwarding power generation in a pumped storage power station

Abstract

The present invention discloses a control method and system for pumped-storage power generation in a pumped-storage power station, relating to the technical field of operating condition conversion in pumped-storage power stations. The method includes: addressing the problem of complex hydraulic fluctuation superposition under a one-pipe, multi-machine arrangement, proposing a phased guide vane control strategy, dynamically adjusting the unit action time interval, and utilizing the negative superposition effect of hydraulic fluctuations to suppress the head deviation of the volute and surge tank; integrating the rapid conversion process with the optimization of control parameters, weakening the traditional ball valve action, using hydraulic braking to shorten the conversion time, and combining Morris sensitivity analysis to screen key parameters; introducing the NSGA-III algorithm to optimize multi-objective indicators, combining TOPSIS scoring to select the Pareto solution set, and obtaining a full-operating condition control scheme that takes into account both stability and speed. The present invention can effectively improve the power grid's power shortage response capability and unit safety.

Description

Technical Field

[0001] The present invention relates to the technical field of operating condition conversion of a pumped storage power station, and in particular to a control method and system for pumping water and transferring power to a pumped storage power station. Background Art

[0002] In the context of the new power system, the increasing proportion of renewable energy generation has led to greater challenges in grid frequency stability, necessitating the rapid response of pumped-storage power plants to power shortages. The traditional pumped-to-hydro power generation process requires multiple downtime phases (e.g., pumping, rotational downtime, downtime hot standby, and idling), with a transition time of up to 438 seconds, making it unable to meet the grid's rapid regulation requirements.

[0003] While existing technologies have proposed rapid conversion solutions (shortening the time to 220 seconds), they rely on hydraulic braking rather than electrical / mechanical braking, and ignore the impact of the complex hydraulic connections between multiple units on stability. This results in the test verifying feasibility only in a single scenario, lacking optimization of control parameters and multi-unit coordinated control strategies. In addition, existing methods face a core contradiction: shortening the conversion time will exacerbate head fluctuations (such as volute head deviation and surge in the surge tank), while excessive pursuit of stability will sacrifice speed. Especially in a single-pipe multi-unit layout, the superposition of hydraulic disturbances between units may cause chain problems such as pipeline resonance and pressure fluctuations, making the existing single-unit control strategy unable to be directly transplanted. For example, in the experiments at the Hongping Power Station, although the rapid conversion process significantly shortened the time, the influence of the guide vane control parameters on stability was not clearly defined, which limited the effectiveness of the engineering application.

[0004] In summary, with respect to the control method of pumping hydropower generation, the existing technology is unable to propose a comprehensive strategy that can simultaneously ensure conversion speed and system stability. Summary of the Invention

[0005] The embodiments of the present invention provide a control method and system for pumping and forwarding power generation in a pumped storage power station, which can propose a comprehensive strategy for simultaneously ensuring conversion speed and system stability.

[0006] An embodiment of the present invention provides a method for controlling pumping and forwarding power generation in a pumped storage power station, comprising the following steps:

[0007] Obtain the control parameters of pumping and forwarding power generation in a pumped storage power station;

[0008] The control parameters were input into the Morris sensitivity analysis model to screen the control parameters that are sensitive to the volute head deviation, draft tube inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation, and operating mode conversion time. The shutdown duration, guide vane opening, and governor integral parameter were obtained as key control parameters.

[0009] The operating conditions during pumping and forwarding power generation are divided into multiple stages, including pump shutdown, hydraulic braking, turbine operating start-up, and frequency regulation. During the multi-stage transition process, the operating time intervals of the pumped storage power station units are dynamically adjusted, and the negative superposition effect of hydraulic fluctuations is used to suppress the deviation of the volute head and the surge tank head.

[0010] Taking the volute head deviation, tailwater inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation and operating condition conversion time as optimization objectives, the multi-objective optimization algorithm NSGA-III is used to obtain the Pareto solution set, and the comprehensive evaluation method TOPSIS is used to obtain the optimal solution from the Pareto solution set. The key control parameters corresponding to the optimal solution are used as the pumping-to-power generation control scheme of the pumped storage power station.

[0011] Furthermore, before inputting the control parameters into the sensitivity analysis model Morris for screening, the method further includes: canceling the switching action of the ball valve and only using hydraulic braking to achieve working condition conversion, thereby shortening the conversion time.

[0012] Furthermore, the dynamic adjustment of the unit's action time interval utilizes the negative superposition effect of hydraulic fluctuations to suppress the deviation of the volute and surge tank water head. The specific steps include:

[0013] The guide vane opening and closing process is divided into multiple stages of dynamic superposition: pump shutdown, hydraulic braking, turbine operating start-up, and frequency regulation, to analyze the time domain characteristics of hydraulic fluctuations.

[0014] During the pump shutdown and frequency adjustment process, the pump shutdown time T1 is extended to reduce the surge well water level fluctuation compared to the original surge well water level fluctuation;

[0015] During turbine startup and frequency regulation, by setting the guide vane opening GV2 to a guide vane opening limit greater than 0.2, the speed regulation is faster than the original speed regulation, and the tailwater pipe head deviation is reduced compared to the original tailwater pipe head deviation;

[0016] For symmetric initial operating conditions and asymmetric initial operating conditions, the preset time interval schemes are matched respectively to achieve the negative superposition of hydraulic fluctuations. The negative superposition effect of hydraulic fluctuations can suppress the volute head deviation and the surge well head deviation.

[0017] Furthermore, the sensitivity analysis model Morris specifically includes:

[0018] The sensitivity discriminant factor is obtained by the sensitivity analysis model Morris SN :

[0019] ;

[0020] ;

[0021] in, Y i and Y i+1 Respectively represent i and i +1 result after the disturbance change; P i and P i+1 Respectively represent i and i +1 The rate of change between the perturbation change value and the initial value; Y 0 is the result corresponding to the initial value; N is the total number of perturbations of the control parameters.

[0022] An embodiment of the present invention provides a control system for pumping and forwarding power generation of a pumped storage power station, comprising:

[0023] A parameter acquisition module is used to obtain the control parameters of the pumped storage power station for pumping and forwarding power generation;

[0024] The time adjustment module is used to input the control parameters into the Morris sensitivity analysis model to screen the control parameters that are sensitive to the volute head deviation, the tailwater pipe inlet head deviation, the upstream surge tank water level deviation, the downstream surge tank water level deviation, the speed deviation, and the operating condition conversion time, and obtain the shutdown duration, the guide vane opening, and the governor integral parameter as the key control parameters; the operating conditions during the pumping and forwarding operation are divided into multiple stages, including: pump shutdown, hydraulic braking, turbine operating condition startup, and frequency regulation; during the conversion process of multiple stages, the action time interval of the pumped storage power station unit is dynamically adjusted, and the volute head deviation and the surge tank head deviation are suppressed by using the negative superposition effect of hydraulic fluctuations;

[0025] The solution acquisition module is used to obtain the Pareto solution set using the multi-objective optimization algorithm NSGA-III, with the volute head deviation, tailwater pipe inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation and operating condition conversion time as optimization objectives. The optimal solution is obtained from the Pareto solution set using the comprehensive evaluation method TOPSIS, and the key control parameters corresponding to the optimal solution are used as the pumping-to-power generation control scheme of the pumped-storage power station.

[0026] The embodiments of the present invention provide a method and system for controlling pumping and forwarding power generation in a pumped storage power station. Compared with the prior art, the method and system have the following beneficial effects:

[0027] The present invention takes the volute head deviation, the tailwater pipe inlet head deviation, the upstream surge tank water level deviation, the downstream surge tank water level deviation, the speed deviation and the operating condition conversion time as optimization objectives, obtains the Pareto solution set through the multi-objective optimization algorithm NSGA-III, and uses the comprehensive evaluation method TOPSIS to obtain the optimal solution from the Pareto solution set, and uses the key control parameters corresponding to the optimal solution as the pumping and forwarding control scheme of the pumped storage power station; among them, the optimization of the conversion time ensures the conversion speed, and at the same time the volute head deviation, the tailwater pipe inlet head deviation, the upstream surge tank water level deviation, the downstream surge tank water level deviation and the speed deviation ensure the stability of the system, so that the control scheme finally obtained is more comprehensive. BRIEF DESCRIPTION OF THE DRAWINGS

[0028] Figure 1 A flowchart provided for an embodiment of the present invention;

[0029] Figure 2 A schematic diagram of the pumping and forwarding power generation operating conditions provided by an embodiment of the present invention;

[0030] Figure 3 A partition diagram of the volute water head and the tailwater pipe water head in the pumping forwarding circuit provided by an embodiment of the present invention;

[0031] Figure 4 A zoning diagram of surge changes in a surge well in a pump-to-transfer system provided by an embodiment of the present invention;

[0032] Figure 5 A diagram showing the influence of time intervals on the stability and rapidity of pumping and forwarding power generation under the symmetrical initial operating condition scenario A2 provided by an embodiment of the present invention;

[0033] Figure 6 A diagram showing the influence of time intervals on the stability and speed of pumping and forwarding under the asymmetric initial operating condition scenario B2 provided by an embodiment of the present invention;

[0034] Figure 7 Scoring results under symmetric initial working conditions and asymmetric initial working conditions provided by an embodiment of the present invention; wherein (a) is a symmetric initial working condition, and (b) is an asymmetric initial working condition. DETAILED DESCRIPTION

[0035] To make the above-mentioned objects, features, and advantages of the present invention more readily apparent, specific embodiments of the present invention are described in detail below with reference to the accompanying drawings. The following description sets forth numerous specific details to facilitate a full understanding of the present invention. However, the present invention can be implemented in many other ways than those described herein, and those skilled in the art may make similar modifications without departing from the scope of the present invention. Therefore, the present invention is not limited to the specific embodiments disclosed below.

[0036] See also Figure 1The embodiment of the present invention provides a method for controlling pumping and forwarding power generation in a pumped storage power station, comprising the following steps:

[0037] Step 1: Obtain the control parameters of the pumped storage power station for pumping and forwarding electricity.

[0038] Step 2: Input the control parameters into the Morris sensitivity analysis model to screen the control parameters that are sensitive to the volute head deviation, tailwater pipe inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation and operating condition conversion time, and obtain the shutdown time, guide vane opening and governor integral parameter as the key control parameters; divide the operating conditions during the pumping and forwarding operation into multiple stages, which include: pump shutdown, hydraulic braking, turbine operating condition start-up and frequency regulation; during the conversion process of multiple stages, dynamically adjust the action time interval of the pumped storage power station unit, and use the negative superposition effect of hydraulic fluctuations to suppress the volute head deviation and surge tank head deviation.

[0039] Step 3: Taking the volute head deviation, tailwater pipe inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation, and operating condition conversion time as optimization objectives, the multi-objective optimization algorithm NSGA-III is used to obtain the Pareto solution set. The comprehensive evaluation method TOPSIS is used to obtain the optimal solution from the Pareto solution set, and the key control parameters corresponding to the optimal solution are used as the pumping-to-power generation control scheme of the pumped-storage power station.

[0040] The specific plan is as follows:

[0041] Depend on Figure 2 The description shows that the key control factors in the process of pumping and forwarding power generation are as follows: (a) pump shutdown time T1; (b) triggering condition for the start of hydraulic braking: reaching NT1 times the rated speed; (c) guide vane opening time T4; (d) guide vane opening GV1 during hydraulic braking; (e) start-up time of the first turbine operating condition T2; (f) starting opening GV2; speed regulator parameters (g) KP, (h) KI and (i) KD in the frequency regulation mode.

[0042] Depend on Figure 3 and Figure 4 It can be seen that under simple operating conditions, the influence of control factors on evaluation indicators.

[0043] S1: Integrate the rapid conversion process with control parameter optimization, weaken the traditional ball valve action, use hydraulic braking to shorten the conversion time, and screen key control parameters based on Morris sensitivity analysis. The key control parameters include pump downtime T1, guide vane opening GV2, and governor integral parameter KI.

[0044] In step S1, by eliminating the "open / close" action of the ball valve in the traditional process and only using hydraulic braking to achieve working condition conversion, the conversion time is shortened. At the same time, the hydraulic resonance time in the bladeless area is also significantly reduced, achieving optimization of rapid conversion.

[0045] In step S1, the control parameter screening mechanism is implemented based on the Morris sensitivity analysis method. The calculation formula is as follows:

[0046] .

[0047] .

[0048] Where Y i and Y i+1 Respectively represent the calculation results after the i-th and i+1-th disturbance changes; P i and P i+1 |SN| represents the rate of change between the i-th and i+1-th perturbation changes and the initial value, respectively; Y0 is the calculation result corresponding to the initial value; N is the total number of perturbations of a control factor; and SN is the sensitivity factor of a control factor to a certain indicator. A larger |SN| indicates a higher sensitivity of the corresponding parameter to the evaluation indicator, meaning that adjusting this parameter can most effectively improve the corresponding evaluation indicator.

[0049] In step S1: Based on the Morris sensitivity analysis method, by calculating the sensitivity factors (|SN|) of the stability and speed performance indicators, the core control parameters are screened out: pump downtime T1, guide vane opening GV2, and governor integral parameter KI.

[0050] S2: To address the hydraulic fluctuation superposition problem in a multi-unit configuration, a phased guide vane control strategy is proposed to dynamically adjust the operating time intervals of adjacent units and utilize the negative superposition effect of hydraulic fluctuations to suppress the head deviation of the volute and surge tank.

[0051] In step S2, in order to solve the problem of hydraulic fluctuation superposition under the arrangement of multiple units in one pipe, this patent sets different working conditions to find the optimal operation strategy. The initial working condition is the working condition when the power shortage occurs and cannot be changed. The final working condition scene selects symmetrical working condition and asymmetrical working condition. The analysis of the pumping and forwarding operation characteristics under these two working conditions can be found in Figure 5 、 Figure 6 .

[0052] For example, the initial operating scenario includes: (A) Units 1 and 2 are both pumping; (B) One of Units 1 and 2 is pumping, and the other is shut down. The final operating scenario includes: (A) Units 1 and 2 are both generating; (B) One of Units 1 and 2 is generating, and the other is shut down.

[0053] Then, the symmetrical operating condition means that in the initial operating condition scenario, units 1 and 2 are both in pumping conditions, and in the final operating condition scenario, units 1 and 2 are also in pumping conditions.

[0054] Asymmetric operating conditions refer to: in the initial operating scenario, one of units 1 and 2 is in pumping condition and the other is in shutdown condition; and in the final operating scenario, one of units 1 and 2 is in power generation condition and the other is in shutdown condition.

[0055] In step S2, a staged guide vane control design is adopted, namely: symmetric initial operating conditions and asymmetric initial operating conditions. The operating condition transition is divided into multiple stages: pump shutdown (region A), hydraulic braking (region C), turbine operating condition startup (region E), and frequency regulation (region G). By dynamically adjusting the action time interval, the superposition of positive hydraulic fluctuations is eliminated: Symmetric initial operating conditions: By setting the time interval between units 1 and 2 to 40 seconds, the maximum head deviation of unit 1's volute and the minimum water level deviation of the surge tank are significantly reduced. Asymmetric initial operating conditions: When the interval is 40 seconds, the maximum head deviation of the tailwater pipe inlet is reduced, and the minimum water level deviation of the downstream surge tank is significantly optimized.

[0056] S3: Introduce the NSGA-III multi-objective optimization algorithm, take the volute head deviation, speed deviation and working condition conversion time as optimization targets, generate the Pareto solution set, and introduce TOPSIS to evaluate the Pareto solution set, select the optimal control scheme, and determine the full working condition control parameters based on comprehensive stability and rapidity. The evaluation results are as follows: Figure 7 .

[0057] for Figure 7 (a), Symmetric initial working condition, the score of the solution set in scenario A1 is higher than that in scenario A2. The highest scores in scenarios A1 and A2 are the 26th and 33rd solutions, with scores of 0.95 and 0.65 respectively. Figure 7 (b) For the asymmetric initial condition, scenario B2 achieves the highest solution score. The top-scoring solutions for scenarios B1, B2, and B3 are the 33rd, 16th, and 9th solutions, with TOPSIS scores of 0.55, 0.81, and 0.46, respectively. The detailed results of the optimal solutions for these different scenarios are summarized in Table 1. (TOPSIS score data is publicly available.)

[0058] Table 1 Sensitivity ranking results of regulatory factors to evaluation indicators

[0059]

[0060] As can be seen from the table, T1 is most sensitive to the minimum head deviation of the volute, the highest upstream surge tank, the lowest water level deviation, and the highest water level deviation of the downstream surge tank. This is because the time when these indicators occur is close to T1 (due to the Figure 3 and 4 As can be seen, T1 has a direct impact on these indicators. GV2 is most sensitive to the maximum volute head deviation and the maximum and minimum head deviations at the draft tube inlet. This is primarily because changes in GV2 directly cause the hydraulic fluctuations in region G to exceed those in other regions (but not exceeding the minimum volute head in region A). NT1 is most sensitive to the minimum surge deviation in the downstream surge tank and the operating mode transition time. This is because changes in NT1 affect the duration of region B, thereby affecting the hydraulic superposition of surges in the downstream surge tank. Furthermore, the duration of region B accounts for a significant proportion of the total operating mode transition time, making NT1 the most sensitive to both indicators. KI is most sensitive to the maximum speed deviation because changes in the governor parameter KI directly affect the degree of speed fluctuation. These parameters, which are most sensitive to various evaluation indicators, are crucial for the stability and speed of the power plant. (Analysis of all-condition control parameters).

[0061] In step S3, the optimized stability indicators (volute head deviation, surge deviation in the surge well, etc.) and the speed index (OCct) are normalized by Z-score. The specific calculation formula is shown below.

[0062] .

[0063] In the formula, Index nodimen is the dimensionless result of different indicators. X can refer to the maximum / minimum head deviation of the volute, the maximum / minimum head deviation of the draft tube inlet, the highest / lowest surge deviation of the upstream and downstream surge tanks, the maximum speed deviation, etc. mean is the average value of the indicator, X std is the standard deviation of the indicator.

[0064] In step S3, NSGA-III is introduced to optimize the control parameters of different operation strategies. The optimization targets in different optimization scenarios are the stability index and speed index during the working condition conversion process. The specific formulas are as follows:

[0065] .

[0066] Where F1 and F2 represent objective functions 1 and 2, respectively. Sta1 and Sta2 represent the stability indices of units 1 and 2, respectively. Spe1 and Spe2 represent the speed indices of units 1 and 2, respectively.

[0067] The stability indicators include the maximum / minimum head deviation of the volute, the maximum / minimum head deviation of the draft tube inlet, the maximum / minimum surge deviation of the upstream and downstream surge tanks, the maximum speed deviation, etc. In order to reduce the impact of the order of magnitude between different variables, the above variables are dimensionless. The specific formula is as follows:

[0068] .

[0069] Where, Hvde max , Hvde min , respectively represent the maximum head deviation of the volute and the minimum head deviation of the volute, Hdde max , Hdde min , respectively represent the maximum head deviation and the minimum head deviation at the tailwater pipe inlet, Husde max 、 Husde min They represent the maximum water level deviation of the upstream surge well and the minimum water level deviation of the upstream surge well respectively. Hlsde max , Hlsde min They represent the maximum water level deviation and the minimum water level deviation of the downstream surge well respectively. ntde max Indicates the maximum speed deviation.

[0070] Among them, the main body of the formula for the speed index is the working condition conversion time, and the specific formula is as follows:

[0071] .

[0072] Where, T end Indicates the time when the unit speed enters the allowable deviation range, T start Indicates the calculation start time.

[0073] An embodiment of the present invention provides a control system for pumping and forwarding power generation of a pumped storage power station, comprising:

[0074] The parameter acquisition module is used to obtain the control parameters of the pumped storage power station for pumping and forwarding power generation.

[0075] The time adjustment module is used to input the control parameters into the sensitivity analysis model Morris to screen the control parameters that are sensitive to the volute head deviation, tailwater pipe inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation and operating condition conversion time, and obtain the shutdown duration, guide vane opening and governor integral parameter as key control parameters; divide the operating conditions during the pumping and forwarding operation into multiple stages, including: pump shutdown, hydraulic braking, turbine operating condition start-up and frequency regulation; during the conversion process of multiple stages, dynamically adjust the action time interval of the pumped storage power station units, and use the negative superposition effect of hydraulic fluctuations to suppress the volute head deviation and surge tank head deviation.

[0076] The solution acquisition module is used to obtain the Pareto solution set using the multi-objective optimization algorithm NSGA-III, with the volute head deviation, tailwater pipe inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation and operating condition conversion time as optimization objectives. The optimal solution is obtained from the Pareto solution set using the comprehensive evaluation method TOPSIS, and the key control parameters corresponding to the optimal solution are used as the pumping-to-power generation control scheme of the pumped-storage power station.

[0077] A specific embodiment is as follows:

[0078] This embodiment discloses a method for controlling pumping and forwarding power generation in a pumped storage power station, and the specific steps are as follows:

[0079] S1. Integrate the rapid conversion process with control parameter optimization, weaken the traditional ball valve action, use hydraulic braking to shorten the conversion time, and screen key control parameters based on Morris sensitivity analysis. The key control parameters include pump downtime T1, guide vane opening GV2, and governor integral parameter KI.

[0080] S2. To address the hydraulic fluctuation superposition problem in a one-pipe, multi-unit arrangement, a phased guide vane control strategy is proposed to dynamically adjust the action time intervals of adjacent units and utilize the negative superposition effect of hydraulic fluctuations to suppress the head deviation of the volute and surge tank.

[0081] S3. The NSGA-III multi-objective optimization algorithm is introduced, with the volute head deviation, speed deviation and operating condition conversion time as the optimization objectives, to generate the Pareto solution set, and the optimal control scheme is selected in combination with the TOPSIS score, and the full operating condition control parameters are determined by comprehensively considering stability and speed.

[0082] The above-described embodiments merely illustrate several implementations of the present invention, and while their descriptions are relatively specific and detailed, they should not be construed as limiting the scope of the patent. It should be noted that a person skilled in the art would be able to make numerous variations and improvements without departing from the spirit of the present invention, all of which fall within the scope of protection of the present invention. Therefore, the scope of protection of the patent for this invention shall be determined by the appended claims.

Claims

1. A method for controlling pumping and forwarding power generation in a pumped storage power station, characterized in that: The following steps are involved: Obtain the control parameters of pumping and forwarding power generation in a pumped storage power station; The control parameters were input into the Morris sensitivity analysis model to screen the control parameters that are sensitive to the volute head deviation, draft tube inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation, and operating mode conversion time. The shutdown duration, guide vane opening, and governor integral parameter were obtained as key control parameters. The operating conditions of the pumping and forwarding power generation process are divided into multiple stages, including: pump shutdown, hydraulic braking, turbine operating start-up and frequency regulation; During the multi-stage conversion process, the operating time interval of the pumped storage power station units is dynamically adjusted, and the negative superposition effect of hydraulic fluctuations is used to suppress the deviation of the volute head and the surge tank head; Taking the volute head deviation, tailwater pipe inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation and operating condition conversion time as optimization objectives, the Pareto solution set is obtained by the multi-objective optimization algorithm NSGA-III, and the optimal solution is obtained from the Pareto solution set using the comprehensive evaluation method TOPSIS. The key control parameters corresponding to the optimal solution are used as the pumping-to-power generation control scheme of the pumped storage power station.

2. A method for controlling pumping and forwarding power generation in a pumped storage power station according to claim 1, characterized in that: Before inputting the control parameters into the sensitivity analysis model Morris for screening, the method further includes: The switching action of the ball valve is cancelled, and only hydraulic braking is used to realize the working condition conversion, which shortens the conversion time.

3. The method for controlling pumping and forwarding power generation of a pumped storage power station according to claim 1, wherein: The method of dynamically adjusting the operation time interval of the pumped storage power station unit and utilizing the negative superposition effect of hydraulic fluctuations to suppress the volute head deviation and the surge tank head deviation specifically includes the following steps: The guide vane opening and closing process is divided into multiple stages of dynamic superposition: pump shutdown, hydraulic braking, turbine operating start-up, and frequency regulation, to analyze the time domain characteristics of hydraulic fluctuations. During the pump shutdown and frequency adjustment process, the pump shutdown time T1 is extended to reduce the surge well water level fluctuation compared to the original surge well water level fluctuation; During turbine startup and frequency regulation, by setting the guide vane opening GV2 to a guide vane opening limit greater than 0.2, the speed regulation is faster than the original speed regulation, and the tailwater pipe head deviation is reduced compared to the original tailwater pipe head deviation; For symmetric initial operating conditions and asymmetric initial operating conditions, the preset time interval schemes are matched respectively to achieve the negative superposition of hydraulic fluctuations. The negative superposition effect of hydraulic fluctuations can suppress the volute head deviation and the surge well head deviation.

4. The method for controlling pumping and forwarding power generation of a pumped storage power station according to claim 1, wherein: The sensitivity analysis model Morris specifically includes: The sensitivity discriminant factor is obtained by the sensitivity analysis model Morris SN : ； ； in, Y i and Y i+1 Respectively represent i and i +1 result after the disturbance change; P i and P i+1 Respectively represent i and i +1 The rate of change between the perturbation change value and the initial value; Y 0 is the result corresponding to the initial value; N is the total number of perturbations of the control parameters.

5. A control system for pumped-storage power generation in a pumped-storage power station, using the control method for pumped-storage power generation in a pumped-storage power station according to any one of claims 1 to 4, characterized in that: include: A parameter acquisition module is used to obtain the control parameters of the pumped storage power station for pumping and forwarding power generation; The time adjustment module is used to input the control parameters into the Morris sensitivity analysis model to screen the control parameters that are sensitive to the volute head deviation, draft tube inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation, and operating condition conversion time. The shutdown duration, guide vane opening, and governor integral parameter are obtained as key control parameters. The operating conditions of the pumping and forwarding power generation process are divided into multiple stages, including: pump shutdown, hydraulic braking, turbine operating start-up and frequency regulation; During the multi-stage conversion process, the operating time interval of the pumped storage power station units is dynamically adjusted, and the negative superposition effect of hydraulic fluctuations is used to suppress the deviation of the volute head and the surge tank head; The solution acquisition module is used to obtain the Pareto solution set using the multi-objective optimization algorithm NSGA-III, with the volute head deviation, tailwater pipe inlet head deviation, upstream surge tank water level deviation, downstream surge tank water level deviation, speed deviation and operating condition conversion time as optimization objectives. The optimal solution is obtained from the Pareto solution set using the comprehensive evaluation method TOPSIS, and the key control parameters corresponding to the optimal solution are used as the pumping-to-power generation control scheme of the pumped-storage power station.

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