Pumping and storage power station control method and system based on pumping coordination
By constructing a three-dimensional hydraulic model and using intelligent optimization algorithms, the coordinated operation of multiple units in a pumped storage power station is achieved, solving the problems of low efficiency and equipment damage in traditional pumped storage power stations under grid regulation requirements, and realizing efficient and safe regulation across the entire range.
Patent Information
- Authority / Receiving Office
- CN · China
- Patent Type
- Applications(China)
- Current Assignee / Owner
- TSINGHUA UNIVERSITY
- Filing Date
- 2026-01-27
- Publication Date
- 2026-05-15
AI Technical Summary
Traditional pumped storage power stations cannot coordinate multiple units under different operating conditions when responding to the grid's demand for refined regulation, resulting in reduced efficiency, equipment damage, and an inability to achieve efficient, safe, and flexible regulation across the entire range.
By constructing a three-dimensional hydraulic model, performing finite element mesh generation and numerical simulation, generating different combined operating conditions, calculating the efficiency and safety index, and combining intelligent optimization algorithms to find the optimal combined operation strategy, the coordinated operation of multiple units can be achieved.
It broadened the operating range of the power station, improved the grid response capability, reduced equipment damage, and enhanced the economic efficiency and safety stability of the power station.
Smart Images
Figure CN122052076A_ABST
Abstract
Description
Technical Field
[0001] This application relates to the field of pumped storage power station technology, and in particular to a pumped storage power station control method and system based on pumping and generation coordination. Background Technology
[0002] With the increasing proportion of fluctuating renewable energy sources such as wind and solar power in the power system, pumped storage power stations, as the most mature and economical large-scale energy storage and regulation tool, are becoming increasingly important due to their flexible operation capabilities. Traditional pumped storage operation modes rely primarily on the macro-level demand of the power grid: when wind and solar power output is excessive and grid load is low, the pumped storage units operate as pumps, converting excess electrical energy into the potential energy of water for storage; when grid load is high or renewable energy output is insufficient, they switch to turbine operation, releasing the potential energy of the water into electrical energy to ensure the power balance and stability of the power grid.
[0003] However, this traditional operating mode faces severe technical challenges. In practical engineering, to respond to the grid's demand for refined regulation, such as when the system only needs to slightly increase or decrease power, traditional pumped-storage power stations often have to operate with a single unit under low flow and low load conditions, far from their design operating conditions. This extreme condition leads to severe deterioration of the internal water flow state, resulting in phenomena such as a sharp decrease in efficiency, flow separation, cavitation, and unstable vortices. Long-term or frequent operation under such adverse conditions not only causes huge energy losses but also triggers severe vibrations and pressure pulsations in the unit, causing irreversible damage to core flow components such as the runner and guide vanes, significantly increasing the power station's maintenance costs and operational safety risks. Fundamentally, existing pumped-storage units are usually designed to switch synchronously to the same operating condition: all pumps or all generators. There is a lack of a refined regulation strategy that enables multiple units within the power station to coordinate and combine turbines and pumps under different operating conditions. This prevents the power station from achieving continuous, flexible, efficient, and safe regulation across the entire range from zero to maximum capacity while ensuring equipment safety. Therefore, developing a new control method for pumped storage power plants to overcome the above-mentioned technical defects has become a key issue that urgently needs to be addressed in this field. Summary of the Invention
[0004] The purpose of this application is to provide a pumped-storage power station control method and system based on pumping and generation coordination, which can solve at least one of the technical problems mentioned in the prior art.
[0005] One aspect of this application provides a pumped-storage power station control method based on pump-generation coordination. The pumped-storage power station includes n generating units, and the operating modes of the generating units include a pump operating mode and a turbine operating mode. In the pump operating mode, the generating units consume grid power and store hydropower; in the turbine operating mode, the generating units release hydropower and transmit power to the grid. The method includes: determining the unit layout, number of units, and efficient operating range of a single unit in a pumped-storage power station; determining an experimental design method and using the determined experimental design method to generate m combined operating conditions with different power generation and power consumption of the n units; performing numerical simulations on the m combined operating conditions, wherein the combined operating conditions include the number of units operating in the pump operating mode and the number of units operating in the turbine operating mode, as well as the operating points of each unit; calculating the efficiency safety index of the pumped-storage power station's internal circulation operation based on the numerical simulation results; fitting the m combined operating conditions and their corresponding efficiency safety indices to obtain the mapping relationship between various combined operating conditions of the pumped-storage power station and the efficiency safety index; and obtaining the optimal combined operation strategy of the pumped-storage power station based on the power generation or power consumption required by the grid dispatch and in conjunction with the mapping relationship.
[0006] Furthermore, the numerical simulation of the m combined operating conditions includes: constructing a three-dimensional hydraulic model covering one main water intake pipeline, one branch pipeline, n sub-water intake pipelines, and the n generating units according to the unit layout of the pumped storage power station; performing finite element mesh generation on the three-dimensional hydraulic model; specifying different inlets and outlets and their boundary conditions and the operating direction of the generating units during the numerical simulation calculation based on the generated m combined operating conditions; setting the interface and performing three-dimensional finite element numerical simulation calculation on the m combined operating conditions.
[0007] Furthermore, the finite element meshing of the three-dimensional hydraulic model includes: dividing the water supply pipeline composed of the main water intake pipeline, the branch pipe and the n sub-water intake pipelines into an integrated mesh; dividing the fixed part of the unit, the movable guide vane and the impeller into three integrated meshes respectively, wherein the fixed part of the unit includes the volute and the fixed guide vane.
[0008] Furthermore, the different inlet and outlet conditions, boundary conditions, and operating directions of the unit during the given numerical simulation calculation process include: In the numerical simulation, if the pumped storage power station operates in the internal circulation pump mode, the inlet is set at the tailrace pipe end, the boundary condition is atmospheric pressure, and the outlet boundary adjustment is set at the main intake pipe end, the boundary condition is the comprehensive inlet flow rate Q. z1 : Q z1 =Q P -QT , If the pumped storage power station operates in an internal circulation turbine mode, the inlet will be located at the main intake pipeline end, and the boundary condition will be the comprehensive outlet flow rate Q. z2 : Q z2 =Q T -Q P , In the formula, Q P Q is the inflow rate of the water pump. T This refers to the outflow rate of the water turbine.
[0009] Furthermore, the step of obtaining the optimal combined operation strategy of the pumped storage power station based on the power generation or power consumption required by the grid dispatch and in conjunction with the mapping relationship includes: obtaining the power generation or power consumption required by the grid dispatch; assessing whether the operation of a single unit meets the requirements for safe and efficient operation; if the requirements for safe and efficient operation are met, then starting the single unit; if not, adopting a combined operation strategy of n units; finding a combined operating condition that meets the grid dispatch requirements from the combined operation strategy of n units; obtaining the corresponding efficiency safety index based on the combined operating condition through the mapping relationship; determining whether the obtained efficiency safety index meets the requirements for safe operation; if the requirements for safe operation are met, then operating in combination according to the combined operating condition; if the requirements for safe operation are not met, then returning to continue executing the above steps of finding a combined operating condition that meets the grid dispatch requirements until the requirements for safe operation are met.
[0010] Furthermore, the step of finding the combined operating conditions that meet the grid dispatching requirements from the joint operation strategy of the n generating units includes: searching for combined operating conditions that meet the grid dispatching requirements from the joint operation strategy of the n generating units using an intelligent optimization algorithm.
[0011] Furthermore, the formula for calculating the efficiency and safety index is as follows: , In the formula, ESI represents the efficiency and safety index; n represents the number of generating units; and i represents the i-th generating unit. , The weights of each sub-indicator are given, and ; Indicates the system stability index; This indicates the unit's operating efficiency.
[0012] Furthermore, the formula for calculating the system stability index is as follows: , In the formula, Here is the pressure pulsation coefficient, where This indicates the pressure pulsation in key components of unit i, such as the volute, guide vanes, or draft tube, expressed in Pa. These are reference values under design conditions. is the vibration coefficient, where This indicates the vibration displacement amplitude of unit i in key parts such as the bearing housing and top cover. These are reference values under design conditions. Here, is the torque ripple coefficient, where This represents the amplitude of shaft torque fluctuation in unit i. These are reference values under design conditions. The vibration frequency proximity coefficient is denoted as , where This indicates the rotational frequency or main excitation frequency of unit i. The natural frequency of the generator set or supporting structure; The weights of each sub-indicator are given, and .
[0013] Furthermore, the step of fitting the m combined operating conditions and their corresponding efficiency and safety indices to obtain the mapping relationship between the various combined operating conditions and the efficiency and safety indices of the pumped storage power station includes: fitting the m combined operating conditions and their corresponding efficiency and safety indices using an approximate model to obtain a fitted approximate model of the pumped storage power station operation mode control strategy with an accuracy greater than a predetermined threshold; based on the approximate model of the pumped storage power station operation mode control strategy, the mapping relationship between the various combined operating conditions and the efficiency and safety indices of the pumped storage power station can be obtained.
[0014] Another aspect of this application provides a pumped-storage power station control system based on pumping-generating coordination. The pumped-storage power station control system includes a memory, a processor, and a computer program stored in the memory. The processor executes the computer program to implement the steps of the pumped-storage power station control method based on pumping-generating coordination as described above.
[0015] The pumped-storage power station control method and system based on pump-generation coordination in one or more embodiments of this application enables pumped-storage power stations to achieve stable and efficient operation even under traditional inefficient operating conditions such as low power generation / consumption or even non-operating conditions through a novel pump-generation coordination operation mode. This greatly expands the actual operable range of the power station, enabling it to respond more comprehensively to the power grid power fluctuations and frequency regulation needs. As a result, it significantly improves the power station's ability to participate in grid deep peak shaving, rapid frequency regulation and other auxiliary services, thereby enhancing the resilience and safety and stability of the power grid.
[0016] The pumped-storage power station control method and system based on pump-and-charge coordination in one or more embodiments of this application actively optimizes the operation of multiple generating units to their respective "comfort zones" of minimum vibration and optimal pressure pulsation, regardless of the total load requirements. This not only improves instantaneous operational quality but also lays a solid foundation for long-term safe and stable operation and extended lifespan of the units by reducing equipment fatigue damage, thereby enhancing the overall energy efficiency and economic performance of the power station operation. Attached Figure Description
[0017] Figure 1 This is a schematic diagram of the operation mode of a pumped-storage power station based on pumping-generating coordination in the internal circulation turbine condition, according to one embodiment of this application.
[0018] Figure 2 This is a schematic diagram of the operation mode of a pumped-storage power station based on pumping-generating coordination in the internal circulation pump condition, according to one embodiment of this application.
[0019] Figure 3 This is a flowchart of a pumped-storage power station control method based on pumping-out coordination, according to one embodiment of this application.
[0020] Figure 4 This is a flowchart illustrating a numerical simulation method for pumped-storage power station operation mode based on pumping-generating coordination, according to one embodiment of this application.
[0021] Figure 5 This is a flowchart of a pumped-storage power station operation mode control strategy method based on pumping-generating coordination, according to one embodiment of this application.
[0022] Figure 6 This is a schematic structural block diagram of a pumped-storage power station control system based on pumping-generating coordination, according to one embodiment of this application. Detailed Implementation
[0023] Exemplary embodiments will now be described in detail, examples of which are illustrated in the accompanying drawings. When the following description relates to the drawings, unless otherwise indicated, the same numerals in different drawings denote the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with this application. Rather, they are merely examples of apparatuses consistent with some aspects of this application as detailed in the appended claims.
[0024] The pumped-storage power station control method and system based on pumping-generating coordination of this application will now be described in detail with reference to the accompanying drawings. Unless otherwise specified, the features of the following embodiments and implementation methods can be combined with each other.
[0025] Figure 1 This illustration reveals a schematic diagram of the operation mode of a pumped-storage power station based on pump-generation coordination in the internal circulation turbine condition, according to one embodiment of this application. Figure 2 This illustration reveals a schematic diagram of the operation mode of a pumped-storage power station based on pump-generation coordination in the internal circulation pump condition, according to an embodiment of this application. Figure 1 and Figure 2 As shown, a pumped storage power station includes n generating units. The following example will be a pumped storage power station with one main water intake pipeline and four generating units. The pumped storage power station also includes a water transmission pipeline consisting of a main water intake pipeline 110, a branch pipeline 120, and n sub-water intake pipelines 130.
[0026] The unit's operating modes include pump operating mode and turbine operating mode. In pump operating mode, the unit consumes grid power and stores water energy; in turbine operating mode, the unit releases water energy and transmits power to the grid.
[0027] Without relying on a large reservoir, an internal circulation operation mode is achieved within the same main water intake pipeline 110, where some units operate in turbine mode and others in pump mode. In the internal circulation operation mode, the large reservoir does not participate in the hydraulic circulation; the hydraulic circulation only occurs between different units 140 within the same main water intake pipeline 110.
[0028] like Figure 1 As shown, when the power consumption of unit 140 operating in pump mode is less than the power generation of unit 140 operating in turbine mode, the pumped storage power station operates in internal circulation turbine mode.
[0029] like Figure 2 As shown, when the power consumption of unit 140 operating in pump mode is greater than the power generation of unit 140 operating in turbine mode, the pumped storage power station operates in internal circulation pump mode.
[0030] This application provides a pumped storage power station control method based on pumping and generation coordination, which can broaden the operating range of pumped storage power stations. Figure 3 A flowchart illustrating a pumped-storage power station control method based on pumping-out coordination according to an embodiment of this application is disclosed. Figure 3 As shown, a pumped-storage power station control method based on pumping-generating coordination according to one embodiment of this application may include steps S1 to S6.
[0031] In step S1, the basic information of the pumped storage power station is determined.
[0032] The basic information of a pumped storage power station may include the arrangement of the pumped storage units 140, the number of units 140 n, and the efficient operating range of a single unit 140.
[0033] Table 1 below shows the high-efficiency operating range of the four units 140 in both turbine and pump operating modes.
[0034] Table 1 In step S2, the experimental design method is determined, and the determined experimental design method is used to generate m combined operating conditions with different power generation and power consumption of n generating units 140.
[0035] Optionally, the experimental design method of this application may include, but is not limited to, the Latin hypercube design method. The Latin hypercube design method can be used to generate m combined operating conditions for n generating units 140 with different power generation and power consumption. In one embodiment of this application, for example, n=4 and m=100. The combined operating conditions include the number of units 140 operating in pump mode and the number of units operating in turbine mode, as well as the operating values of each unit 140. For example, a combined operating condition in which Unit 140 and Unit 240 operate at 90% and 80% pump operating mode respectively, and Unit 340 and Unit 440 operate at 60% and 50% turbine operating mode respectively; or a combined operating condition in which Unit 140, Unit 240, and Unit 340 operate at 90%, 90%, and 80% pump operating mode respectively, and Unit 440 operates at 70% turbine operating mode, etc.
[0036] In step S3, numerical simulations are performed on m combined operating conditions.
[0037] In some embodiments, step S3, which involves numerically simulating m combined operating conditions, may include steps S31 to S35.
[0038] In step S31, based on the arrangement of the pumped storage power station's units 140, a three-dimensional hydraulic model is constructed, encompassing one main water intake pipeline 110, one branch pipeline 120, n sub-water intake pipelines, and n units 140, such as... Figure 1 and Figure 2 As shown.
[0039] In step S32, the three-dimensional hydraulic model is meshed using the finite element method.
[0040] The water supply pipeline consisting of the main water inlet pipe 110, the branch pipe 120, and n sub-water inlet pipes 130 can be treated as an integrated grid, avoiding excessive interfaces that could increase the uncertainty of grid information transmission. In the unit 140 section, the fixed part, the movable guide vanes, and the impeller of the unit 140 can be divided into three integrated grids. The fixed part of the unit 140 includes the volute and the fixed guide vanes.
[0041] In step S33, based on the generated m combined operating conditions, different inlets and outlets and their boundary conditions and the operating direction of unit 140 are given during the numerical simulation calculation process.
[0042] In the numerical simulation, if the pumped storage power station operates in the internal circulation pump mode, the inlet is set at the tailrace pipe end, the boundary condition is atmospheric pressure, and the outlet boundary adjustment is set at the main intake pipe 110 end, the boundary condition is the comprehensive inlet flow rate Q. z1 : Q z1 =Q P -Q T If the pumped storage power station operates in the internal circulation turbine mode, then the inlet will be located at the 110 end of the main intake pipeline, and the boundary condition will be the comprehensive outlet flow rate Q. z2 : Q z2 =Q T -Q P In the formula, Q P Q is the inflow rate of the water pump. T This refers to the outflow rate of the water turbine.
[0043] For example, based on the 100 combined operating conditions generated, it is determined whether the overall unit operation mode of the pumped storage power station after the four units (140) are operating in the internal circulation turbine mode or the internal circulation pump mode. Based on the calculated internal circulation operating mode, different inlet and outlet conditions and boundary conditions are set for the three-dimensional hydraulic model, and the rotation direction of unit 140 is given.
[0044] In step S34, the interface is set and three-dimensional finite element numerical simulation calculations are performed on m combined working conditions.
[0045] In step S4, the efficiency safety index (ESI) for the internal circulation operation of the pumped storage power station is calculated based on the results of the numerical simulation.
[0046] Figure 4 A flowchart illustrating a numerical simulation method for pumped-storage power station operation mode based on pumping-generating coordination, according to an embodiment of this application, is provided. Figure 4 As shown, step 401: Determine model parameters; step 402: Construct the fluid domains of the main water intake pipeline 110, the branch pipe 120, the sub-water intake pipeline 130, and the unit 140; step 403: Perform mesh generation; step 404: Set the interface; step 405: Select a suitable turbulence model; step 406: Set specific boundary conditions according to the operating combination mode; step 407: Perform numerical simulation calculation; step 408: Extract pressure pulsation, torque, vibration, frequency, and efficiency; step 409: Calculate the efficiency safety index (ESI).
[0047] In some embodiments, the Efficiency Safety Index (ESI) is calculated using the following formula: In the formula, n represents the number of generating units; i represents the i-th generating unit; , The weights of each sub-indicator are given, and Weights of each sub-indicator , It can be determined based on empirical values; Indicates the system stability index; This indicates the unit's operating efficiency.
[0048] In some embodiments, the system stability index The calculation formula is as follows: In the formula, Here is the pressure pulsation coefficient, where This indicates the pressure pulsation in key components of unit i, such as the volute, guide vanes, or draft tube, expressed in Pa. These are reference values under design conditions. is the vibration coefficient, where This indicates the vibration displacement amplitude of unit i in key parts such as the bearing housing and top cover. These are reference values under design conditions. Here, is the torque ripple coefficient, where This represents the amplitude of shaft torque fluctuation in unit i. These are reference values under design conditions. The vibration frequency proximity coefficient is denoted as , where This indicates the rotational frequency or main excitation frequency of unit i. This is the natural frequency of the unit 140 or its supporting structure; this value is mainly used to assess the risk of resonance. The weights of each sub-indicator are given, and Weights of each sub-indicator It can be determined based on empirical values.
[0049] The unit operating efficiency in the above formula Pressure pulsation Vibration displacement amplitude Shaft torque fluctuation amplitude Rotation frequency or main excitation frequency It can be obtained during the numerical simulation process.
[0050] In step S5, the m combined operating conditions and their corresponding Efficiency Safety Index (ESI) are fitted to obtain the mapping relationship between the various combined operating conditions of the pumped storage power station and the ESI.
[0051] In some embodiments, step S5, which involves fitting m combined operating conditions and their corresponding Efficiency Safety Index (ESI) to obtain the mapping relationship between various combined operating conditions of the pumped storage power station and the ESI, may include steps S51 to S53.
[0052] In step S51, an approximate model is used to fit m combined operating conditions and their corresponding efficiency safety index (ESI).
[0053] Alternatively, approximate models such as the Kriging model or the BP (Back Propagation) artificial neural network model can be used to fit m combined operating conditions and their corresponding efficiency safety index (ESI).
[0054] In step S52, it is determined whether the model's accuracy is greater than a predetermined threshold, for example, accuracy. If the result of the judgment is "yes", the process proceeds to step S53. Otherwise, it returns to step S51 to continue the fitting process.
[0055] In step S53, a fitted approximate model of the pumped storage power station operation mode control strategy with an accuracy greater than a predetermined threshold can be obtained. Based on the approximate model of the pumped storage power station operation mode control strategy, the mapping relationship between various combinations of operating conditions and efficiency and safety indices of the pumped storage power station can be obtained.
[0056] In step S6, the optimal combination operation strategy of pumped storage power stations is obtained based on the power generation or power consumption required by the power grid dispatch and in combination with the mapping relationship.
[0057] Figure 5 A flowchart illustrating a pumped-storage power station operation mode control strategy method based on pumping-out coordination according to an embodiment of this application is disclosed. Figure 5 As shown, in some embodiments, step S6, which involves obtaining the optimal combined operation strategy of the pumped storage power station based on the power generation or power consumption required by the grid dispatch and in conjunction with the mapping relationship, may include steps S61 to S69.
[0058] In step S61, the power grid dispatch instruction is obtained.
[0059] In step S62, the power generation or power consumption required for grid dispatch is obtained.
[0060] In step S63, a single unit operation stability assessment is performed.
[0061] In step S64, it is determined whether the operation of a single unit meets the requirements for safe and efficient operation. If the result of the determination is "yes", the process proceeds to step S65. Otherwise, the process proceeds to step S66.
[0062] In step S65, if the requirements for safe and efficient operation are met, then the operation of a single unit is started.
[0063] In step S66, if the conditions are not met, a joint operation strategy of n generating units is adopted to find a combination of operating conditions that meet the grid dispatching requirements from the joint operation strategy of n generating units.
[0064] In some embodiments, intelligent optimization algorithms, such as gravity search or particle swarm optimization, can be used to search for combined operating conditions that meet the grid dispatch requirements from the joint operation strategy of n generating units.
[0065] In step S67, the mapping relationship between the combined operating conditions and the corresponding efficiency and safety index is obtained through the approximate model of the pumped storage power station operation mode control strategy based on the combined operating conditions, thereby obtaining the corresponding efficiency and safety index.
[0066] In step S68, it is determined whether the obtained efficiency safety index meets the safe operation requirements, for example, whether ESI ≥ 0.8. If the result of the determination is "yes", the process proceeds to step S69.
[0067] In step S69, if the safety operation requirements are met, then the combined operation is carried out according to the combined operating condition. If the result of step S68 is "no", that is, the safety operation requirements are not met, then return to step S66 and repeat the step of finding the combined operating condition that meets the grid dispatching requirements until the safety operation requirements are met.
[0068] The pumped storage power station control method based on pumping and generating coordination proposed in this application breaks the limitation of the traditional pumped storage power station where units within the same main water intake pipeline must operate under the same pump or turbine operating conditions. It proposes a combined operation mode and regulation and control strategy that allows multiple units within the same main water intake pipeline of the pumped storage power station to operate in coordinated turbine and pump conditions simultaneously. This can solve the technical problem that the traditional operating mode unit 140 cannot safely and efficiently respond to the low-power regulation needs of the power grid.
[0069] The pumped storage power station control method based on pumping and generating coordination proposed in this application dynamically allocates the operating modes and head / flow of different units through intelligent optimization algorithms, so that the sum of the net output power of multiple units accurately matches the grid demand, while ensuring that each unit operates within its designed safe, efficient and stable zone.
[0070] The pumped storage power station control method based on pumping-generator coordination proposed in this application effectively avoids safety problems such as efficiency drop, cavitation, and vibration caused by the operation of a single unit under extreme low flow conditions. It significantly expands the overall adjustable range and operational flexibility of the pumped storage power station, realizes safe, efficient, and precise regulation of the pumped storage power station across the entire operating range, enhances its ability to absorb fluctuating renewable energy and its ancillary service capabilities to the grid, while reducing unit wear and maintenance costs and ensuring the long-term operational safety and economy of the power station.
[0071] This application also provides a pumped storage power station control system 600 based on pumping and generation coordination. Figure 6 A schematic block diagram of a pumped-storage power station control system 600 based on pumping-generating coordination, according to one embodiment of this application, is shown. Figure 6 As shown, an embodiment of the pumped-storage power station control system 600 based on pumping-out coordination includes a processor 601, an internal bus 602, a network interface 603, a memory 604, and a non-volatile memory 605. It may also include other hardware required for various operations. The processor 601 can read the corresponding computer program from the non-volatile memory 605 into the memory 604 and then run it to implement the steps of the pumped-storage power station control method based on pumping-out coordination as described above. Of course, besides software implementation, this application does not exclude other implementation methods, such as logic devices or a combination of hardware and software, etc. That is to say, the execution entity of the following processing flow is not limited to individual logic units, but can also be hardware or logic components.
[0072] The pumped-storage power station control method and system based on pump-generation coordination proposed in this application, through a novel pump-generation coordination operation mode, enables pumped-storage power stations to still find stable and efficient operation under traditional inefficient operating conditions such as low power generation / consumption or even non-operating conditions. This greatly expands the actual operable range of the power station, enabling it to respond more comprehensively to the power grid power fluctuations and frequency regulation needs, thereby significantly improving the power station's ability to participate in grid deep peak shaving, rapid frequency regulation and other auxiliary services, and enhancing the resilience and safety and stability of the power grid.
[0073] The pumped-storage power station control method and system based on pumping-generator coordination proposed in this application actively optimizes the system to ensure that the operating values of multiple generating units are coordinated and guided to their respective "comfort zones" of minimum vibration and optimal pressure pulsation, regardless of the total load requirements. This not only improves instantaneous operating quality but also lays a solid foundation for the long-term safe and stable operation and extended lifespan of the units by reducing equipment fatigue damage, thereby enhancing the overall energy efficiency and economic performance of the power station operation.
[0074] The above provides a detailed description of the pumped-storage power station control method and system based on pump-discharge coordination provided in the embodiments of this application. Specific examples have been used to illustrate the pumped-storage power station control method and system based on pump-discharge coordination in this document. The descriptions of the embodiments are merely for the purpose of helping to understand the core ideas of this application and are not intended to limit this application. It should be noted that those skilled in the art can make various improvements and modifications to this application without departing from the spirit and principles of this application, and all such improvements and modifications should fall within the protection scope of the appended claims.
Claims
1. A pumped storage power station control method based on pumping-generating coordination, wherein the pumped storage power station includes n generating units, and the operating modes of the generating units include a pump operating mode and a turbine operating mode. In the pump operating mode, the generating units consume grid power and store water energy. In the aforementioned turbine operating mode, the unit releases hydroelectric energy and transmits electrical energy to the power grid, characterized in that... The method includes: Determine the unit layout, number of units, and efficient operating range of a single unit for the pumped storage power station; A design method for experiments is determined, and m combined operating conditions with different power generation and power consumption of the n generating units are generated using the determined design method. Numerical simulations are performed on the m combined operating conditions, wherein the combined operating conditions include the number of generating units operating in the pump operating mode and the number of generating units operating in the turbine operating mode, as well as the operating points of each generating unit. Based on the results of numerical simulation, the efficiency safety index of the pumped storage power station's internal circulation operation was calculated. By fitting the m combined operating conditions and their corresponding efficiency and safety indices, the mapping relationship between the various combined operating conditions and the efficiency and safety indices of the pumped storage power station is obtained. The optimal combined operation strategy for the pumped storage power station is obtained based on the power generation or power consumption required by the power grid dispatch and in conjunction with the mapping relationship.
2. The pumped storage power station control method as described in claim 1, characterized in that, The numerical simulation of the m combined working conditions includes: Based on the unit layout of the pumped storage power station, a three-dimensional hydraulic model is constructed, which includes one main water intake pipeline, one branch pipeline, n sub-water intake pipelines, and the n units. The three-dimensional hydraulic model is meshed using the finite element method. Based on the generated m combined operating conditions, different inlet and outlet conditions and their boundary conditions and the operating direction of the unit are given in the numerical simulation calculation process; Set up the interface and perform three-dimensional finite element numerical simulation calculations on the m combined working conditions.
3. The pumped storage power station control method as described in claim 2, characterized in that, The finite element mesh generation of the three-dimensional hydraulic model includes: The water supply pipeline consisting of the main water inlet pipeline, the branch pipe and the n sub-water inlet pipelines is regarded as an integrated grid. The unit's fixed part, movable guide vanes, and impeller are divided into three integrated grids. The fixed part of the unit includes the volute and fixed guide vanes.
4. The pumped storage power station control method as described in claim 2, characterized in that, The given numerical simulation process includes different inlet and outlet conditions, boundary conditions, and unit operating directions, including: In the numerical simulation, if the pumped storage power station operates in the internal circulation pump mode, the inlet is set at the tailrace pipe end, the boundary condition is atmospheric pressure, and the outlet boundary adjustment is set at the main intake pipe end, the boundary condition is the comprehensive inlet flow rate Q. z1 : Q z1 =Q P -Q T , If the pumped storage power station operates in an internal circulation turbine mode, the inlet will be located at the main intake pipeline end, and the boundary condition will be the comprehensive outlet flow rate Q. z2 : Q z2 =Q T -Q P , In the formula, Q P Q is the inflow rate of the water pump. T This refers to the outflow rate of the water turbine.
5. The pumped storage power station control method as described in claim 1, characterized in that, The optimal combined operation strategy for the pumped storage power station, derived from the power generation or consumption demand of the power grid dispatch and in conjunction with the mapping relationship, includes: To obtain the power generation or power consumption required for power grid dispatch; Assess whether the operation of a single unit meets the requirements for safe and efficient operation; If the requirements for safe and efficient operation are met, a single unit will be started; otherwise, a strategy of joint operation of n units will be adopted. Find the combined operating conditions that meet the grid dispatching requirements from the joint operation strategy of the n generating units; Based on the combined operating conditions and the mapping relationship, the corresponding efficiency and safety index is obtained; Determine whether the obtained efficiency and safety index meets the requirements for safe operation; If the safety operation requirements are met, then the combined operation shall be carried out according to the combined operating conditions; if the safety operation requirements are not met, then return to the above steps of finding the combined operating conditions that meet the power grid dispatching requirements until the safety operation requirements are met.
6. The pumped storage power station control method as described in claim 5, characterized in that, The step of finding the combined operating conditions that meet the grid dispatch requirements from the joint operation strategy of the n generating units includes: The intelligent optimization algorithm searches for combined operating conditions that meet the grid dispatching requirements from the joint operation strategies of the n generating units.
7. The pumped storage power station control method as described in claim 1, characterized in that, The formula for calculating the efficiency and safety index is as follows: , In the formula, ESI represents the efficiency and safety index; n represents the number of generating units; and i represents the i-th generating unit. , The weights of each sub-indicator are given, and ; Indicates the system stability index; This indicates the unit's operating efficiency.
8. The pumped storage power station control method as described in claim 7, characterized in that, The formula for calculating the system stability index is as follows: , In the formula, Here is the pressure pulsation coefficient, where This indicates the pressure pulsation in key components of unit i, such as the volute, guide vanes, or draft tube, expressed in Pa. These are reference values under design conditions. is the vibration coefficient, where This indicates the vibration displacement amplitude of unit i in key parts such as the bearing housing and top cover. These are reference values under design conditions. Here, is the torque ripple coefficient, where This represents the amplitude of shaft torque fluctuation in unit i. These are reference values under design conditions. The vibration frequency proximity coefficient is denoted as , where This indicates the rotational frequency or main excitation frequency of unit i. The natural frequency of the generator set or supporting structure; The weights of each sub-indicator are given, and .
9. The pumped storage power station control method as described in claim 1, characterized in that, The process of fitting the m combined operating conditions and their corresponding efficiency and safety indices to obtain the mapping relationship between various combined operating conditions and efficiency and safety indices of the pumped storage power station includes: By fitting the m combined operating conditions and their corresponding efficiency and safety indices using an approximate model, an approximate model of the control strategy for the pumped storage power station operation mode with an accuracy greater than a predetermined threshold is obtained. Based on the approximate model of the pumped storage power station operation mode control strategy, the mapping relationship between various combinations of operating conditions and efficiency and safety indices of the pumped storage power station can be obtained.
10. A pumped-storage power station control system based on pumping-generating coordination, comprising a memory, a processor, and a computer program stored in the memory, characterized in that, The processor executes the computer program to implement the steps of the pumped storage power station control method based on pumping coordination as described in any one of claims 1 to 9.