A Distributed Power Generation Dispatch System and Method for Reservoir Groups

Abstract

This invention discloses a distributed generation dispatching system and method for reservoir groups, specifically relating to the field of hydropower dispatching technology. It includes a hydropower digital twin model construction module, a distributed power source data acquisition module, a generator unit generation regulation module, a photovoltaic energy storage generation regulation module, and a distributed power source load early warning module. This invention collects distributed power source data from each monitoring sub-region of the reservoir group, calculates the reservoir unit capacity dispatchability index to determine the unit efficiency in different sub-regions, and, combined with turbine flow rate, maintains the stability of high-efficiency unit operation while improving the power output of inefficient units. By calculating the photovoltaic energy storage dispatchability index and using a capacity allocation algorithm for energy storage power supply, it improves the stability and efficiency of reservoir group power generation dispatching. It also assesses the line load rate of each monitoring sub-region of the reservoir group to prevent grid load on power generation dispatching. Through multi-source power superposition, the load rate reflects line pressure, thereby enhancing grid security.

Description

Technical Field

[0001] This invention relates to the field of hydropower dispatching technology, and more specifically, to a distributed power generation dispatching system and method for a group of reservoirs. Background Technology

[0002] Economic operation of hydropower stations and optimized reservoir scheduling are measures to increase power generation by maximizing the storage and regulation potential of hydropower station equipment and reservoirs, and to fully utilize water energy. They also serve as an energy-saving measure to reduce the consumption of other energy sources in the power system and are important means of scientific management of hydropower stations. Modernized economic operation and optimized reservoir scheduling of hydropower stations focuses on the reservoirs of hydropower stations, cascade (basin) hydropower stations, and solar-hydropower complementarity projects within reservoir areas. This aims to achieve automated integration of reservoir scheduling, reduce water wastage rates, and enhance peak-shaving capacity.

[0003] The scheduling problem of reservoir groups is essentially a highly nonlinear mathematical programming problem. As the scale of the reservoir group increases, its solution space becomes extremely large and irregular. In actual management, when the reservoir operates at a low water level for a long time, the power generation efficiency is reduced. If the hydropower station units are opened to the maximum regardless of the water level, the unit operating efficiency will decrease and the utilization rate of the power generation flow will decrease, thus causing the units to be in an unstable operating state.

[0004] However, in actual use, it still has some shortcomings, such as the wide distribution of the existing power generation dispatching reservoir group, which leads to grid fluctuation problems caused by the dispersion, intermittency and randomness of distributed power sources, and the power supply stability is not perfect.

[0005] The existing reservoir system is widely distributed, and aging or malfunctions may lead to data distortion, increased equipment failure rate, and decreased data reliability. Under extreme weather conditions, the reservoir system's response capacity is insufficient, making it difficult to meet real-time dispatch requirements and potentially causing safety hazards. Summary of the Invention

[0006] To overcome the aforementioned deficiencies of the prior art, embodiments of the present invention provide a distributed power generation dispatching system for reservoir groups, which addresses the problems mentioned in the background art.

[0007] To achieve the above objectives, the present invention provides the following technical solution: a distributed generation dispatching system for a reservoir group, comprising:

[0008] Hydropower Digital Twin Model Construction Module: This module is used to aggregate and model reservoir power stations and surface photovoltaic power plants within a reservoir group into virtual power plants, thereby constructing a digital twin model of distributed hydropower.

[0009] Distributed power source data acquisition module: used to collect distributed power source data from each monitoring sub-area of ​​the reservoir group. The distributed power source data acquisition module includes a generator power generation data acquisition unit and a photovoltaic power generation data acquisition unit. The distributed power source data includes generator power generation data and photovoltaic power generation data.

[0010] Unit power generation regulation module: Used to receive distributed power data transmitted by the distributed power data acquisition module, calculate the reservoir capacity dispatchability index of each monitoring sub-area of ​​the reservoir group based on the unit power generation data collected by the unit power generation data acquisition unit, and divide the regulation measures for different unit operating areas.

[0011] Photovoltaic energy storage power generation regulation module: It is used to receive distributed power data transmitted by the distributed power data acquisition module, calculate the photovoltaic energy storage dispatchability index of each monitoring sub-area of ​​the reservoir group based on the photovoltaic power generation data collected by the photovoltaic power generation data acquisition unit, and call on the photovoltaic power generation equipment to provide energy storage power supply.

[0012] Distributed power load early warning module: Based on the smart meters in each monitoring sub-area of ​​the reservoir group, the distributed power load data is collected, the line load rate of each monitoring sub-area of ​​the reservoir group is assessed, and the power generation scheduling grid load is prevented.

[0013] Preferably, the hydropower digital twin model construction module:

[0014] The reservoir power stations and surface photovoltaic power plants within the reservoir group are aggregated and modeled as virtual power plants, connecting the power generation of the reservoir power stations and the surface photovoltaic power plants to form a collaborative scheduling system. A 3D modeling technology is used to create a 3D model of the reservoir group, constructing a digital twin model of distributed hydropower. The reservoir group is divided into monitoring sub-regions according to an equal area division method, and each monitoring sub-region is sequentially numbered 1, 2, ... i, ... n, and associated with the digital twin model.

[0015] Preferably, the distributed power source data acquisition module specifically comprises:

[0016] The generator set data acquisition unit collects the turbine inlet water level, turbine outlet water level, and turbine power output for each monitoring sub-area of ​​the reservoir group, and marks them as follows: , , , where i=1,2,...n, i represents the number of the i-th monitoring sub-region, which is associated with the digital twin model;

[0017] Photovoltaic power generation data acquisition unit: Collects the upper limit of energy storage charging and discharging power, rated power of surface photovoltaic installations, rated energy storage capacity, and average daily photovoltaic power generation for each monitoring sub-area of ​​the reservoir group, and marks them as follows: , , , It is associated with the digital twin model.

[0018] Preferably, the generator set power generation regulation module specifically comprises:

[0019] Step S41: Based on the turbine inlet water level, turbine outlet water level, and turbine power generation output, calculate the reservoir capacity dispatchability index of each monitoring sub-region of the reservoir group;

[0020] Step S42: Establish the logic for judging the efficient operation zone: When the reservoir unit capacity dispatchability index The preset reservoir capacity dispatchability index and the minimum turbine flow rate. turbine flow rate The maximum value of the turbine flow rate indicates that the reservoir unit in the monitored sub-area is in a high-efficiency operating zone. Increase the inflow rate of the reservoir in the high-efficiency operating zone and correlate it with the digital twin model.

[0021] Step S43: Establish the logic for judging inefficient operating areas: When the reservoir unit capacity dispatchability index The preset reservoir capacity dispatchability index and turbine flow rate The maximum value of the turbine flow rate indicates that the reservoir units in the monitored sub-area are in an inefficient operating zone. The turbine power output of the monitored sub-area is obtained, and the turbine power output range is adjusted to (minimum turbine power output and maximum turbine power output) to reduce the reservoir inflow in the inefficient operating zone. This is then correlated with the digital twin model.

[0022] Step S44: Establish the logic for determining the no-load operation zone: When the reservoir unit's capacity dispatchability index... The preset reservoir capacity dispatchability index and turbine flow rate The minimum flow rate of the turbine indicates that the reservoir units in the monitored sub-area are in an unloaded operating zone. The reservoir units in the monitored sub-area are then shut down and associated with the digital twin model.

[0023] Preferably, the photovoltaic energy storage power generation regulation module specifically comprises:

[0024] S51: Based on the upper limit of energy storage charging and discharging power, the rated power of surface photovoltaic installations, the rated capacity of energy storage, and the average daily power generation of photovoltaics, calculate the photovoltaic energy storage dispatchability index of each monitoring sub-region of the reservoir group;

[0025] S52: Obtain photovoltaic output. Calculate the photovoltaic adjustable margin of each monitoring sub-region of the reservoir group by subtracting the maximum photovoltaic output value from the photovoltaic output value. If the photovoltaic adjustable margin of a certain monitoring sub-region is greater than the preset photovoltaic adjustable margin, it indicates that the monitoring sub-region is a photovoltaic priority power supply area, with a quantity of m. Conversely, it indicates that the monitoring sub-region is a photovoltaic energy storage area, and is associated with the digital twin model.

[0026] Preferably, the step of using photovoltaic power generation equipment for energy storage and power supply specifically involves:

[0027] Obtain the available photovoltaic energy storage capacity. If the available photovoltaic energy storage capacity is less than the minimum available photovoltaic energy storage capacity, call on the photovoltaic power generation equipment on the reservoir surface in the photovoltaic priority power supply area to simultaneously provide energy storage power supply. Calculate the energy storage capacity allocated to the photovoltaic power generation equipment on the reservoir surface in the photovoltaic priority power supply area according to the energy storage capacity allocation algorithm, and associate it with the digital twin model.

[0028] Preferably, the distributed power supply load early warning module specifically comprises:

[0029] S71: The distributed power load data includes the active power of the distributed power sources in each monitoring sub-region. Reactive power of distributed power sources Active power of the load reactive power of the load ;

[0030] S72: Calculate the actual active power transmitted by the lines in each monitoring sub-area: ;

[0031] S73: Calculate the actual reactive power transmitted by the lines in each monitoring sub-area:

[0032] S74: Calculate the actual apparent power of the lines in each monitoring sub-region:

[0033] S75: Extract the maximum actual apparent power of the reservoir group's power lines. The formula for calculating the line load rate is: ,

[0034] in, Let represent the line load rate of the i-th monitoring sub-region. This represents the actual apparent power of the line in the i-th monitoring sub-region. This represents the maximum actual apparent power of the line;

[0035] S76: Obtain the line load rate of each monitoring sub-region of the reservoir group and compare it with the preset line load rate. If the line load rate of a certain monitoring sub-region... If the preset line load rate is too high, it indicates that there is an overload risk in the monitored sub-area, and an immediate power grid load warning should be issued. Conversely, if the preset line load rate is too low, it indicates that the distributed generation dispatching in the monitored sub-area is operating normally and can be correlated with the digital twin model.

[0036] A method for dispatching distributed generation in a reservoir group includes the following steps:

[0037] Step S01: Combine the reservoir power stations within the reservoir group with the surface photovoltaic power plants in the reservoir area to form a virtual power plant, and construct a digital twin model of distributed hydropower.

[0038] Step S02: Collect distributed power generation data for each monitoring sub-area of ​​the reservoir group, including generator power generation data and photovoltaic power generation data;

[0039] Step S03: Based on the collected generator power generation data, calculate the reservoir capacity dispatchability index of each monitoring sub-region of the reservoir group, and divide the regulation measures for different unit operating areas;

[0040] Step S04: Based on the collected photovoltaic power generation data, calculate the photovoltaic energy storage dispatchability index of each monitoring sub-area of ​​the reservoir group, and call upon the photovoltaic power generation equipment for energy storage power supply;

[0041] Step S05: Collect distributed power load data from smart meters in each monitoring sub-area of ​​the reservoir group, assess the line load rate in each monitoring sub-area of ​​the reservoir group, and prevent power generation from disrupting grid load.

[0042] The technical effects and advantages of this invention are as follows:

[0043] 1. This invention provides a distributed generation dispatching system and method for reservoir groups. It constructs a digital twin model of distributed hydropower by aggregating and modeling reservoir power stations and surface photovoltaic power plants within the reservoir group into a virtual power plant. Distributed power source data from each monitoring sub-region of the reservoir group are collected. Based on the power generation data collected by the unit power generation data acquisition unit, the reservoir capacity dispatchability index of each monitoring sub-region of the reservoir group is calculated. Rules for determining high-efficiency operation zones, inefficient operation zones, and no-load operation zones are established to classify adjustment measures for different unit operation zones. The results are correlated with the digital twin model. Through digital technology, reservoir power stations and surface photovoltaic power plants within the reservoir group are deeply integrated and aggregated into a virtual power plant, constructing a digital twin model of distributed hydropower. This enables monitoring of power generation status in the virtual scenario. The unit efficiency in different sub-regions is determined by the reservoir capacity dispatchability index. Combined with turbine flow rate, the stability of high-efficiency power generation units in the reservoir is maintained, improving the efficiency of the reservoir. To reduce hydraulic losses, the power output of inefficient generating units is reduced. Based on the photovoltaic power generation data collected by the photovoltaic power generation data acquisition unit, the dispatchability index of photovoltaic energy storage in each monitoring sub-region of the reservoir group is calculated. Through the photovoltaic adjustability margin, priority photovoltaic power supply areas are selected, and the available photovoltaic energy storage capacity is obtained. If the available photovoltaic energy storage capacity is less than the minimum available photovoltaic energy storage capacity, the photovoltaic power generation equipment on the reservoir surface in the priority photovoltaic power supply area is called to simultaneously provide energy storage power supply. The energy storage capacity allocated to the photovoltaic power generation equipment on the reservoir surface in the priority photovoltaic power supply area is calculated according to the energy storage capacity allocation algorithm and associated with the digital twin model. By processing the photovoltaic power generation data of each monitoring sub-region of the reservoir group, priority photovoltaic power supply areas and photovoltaic energy storage areas are selected, dynamically adapting to power supply demand and reducing redundant energy storage calls. The capacity allocation algorithm ensures the timeliness of emergency energy replenishment and avoids excessive calls in individual areas that lead to subsequent power supply capacity imbalance, thereby improving the stability and efficiency of power generation scheduling in the reservoir group.

[0044] 2. This invention provides a distributed generation dispatching system and method for reservoir groups. Based on smart meters in each monitoring sub-area of ​​the reservoir group, it collects the active power and reactive power of distributed power sources, the active power of loads, and the reactive power of loads. It then assesses the line load rate of each monitoring sub-area of ​​the reservoir group and compares it with a preset line load rate. If the line load rate of a certain monitoring sub-area... The preset line load rate indicates that the line load rate of the monitored sub-area is too high and there is an overload risk. The grid load warning should be issued immediately. Conversely, it indicates that the distributed generation dispatch of the monitored sub-area is operating normally. It is associated with the digital twin model, takes into account the impact of line loss on the load rate, calculates the load rate to reflect the line pressure through the superposition of multiple power sources, and issues graded warnings to improve grid security. Attached Figure Description

[0045] Figure 1This is a schematic diagram of the structure of a distributed power generation dispatching system for a reservoir group according to the present invention.

[0046] Figure 2 This is a schematic diagram of the distributed power data acquisition module of the present invention.

[0047] Figure 3 This is a flowchart illustrating a distributed generation scheduling method for a reservoir group according to the present invention. Detailed Implementation

[0048] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0049] Please see Figure 1 As shown, the present invention provides a distributed power generation scheduling system for reservoir groups, including a hydropower digital twin model construction module, a distributed power source data acquisition module, a generator unit power generation regulation module, a photovoltaic energy storage power generation regulation module, and a distributed power source load early warning module.

[0050] The hydropower digital twin model construction module is connected to the distributed power source data acquisition module, the distributed power source data acquisition module is connected to the unit power generation regulation module and the photovoltaic energy storage power generation regulation module, and the unit power generation regulation module and the photovoltaic energy storage power generation regulation module are connected to the distributed power source load early warning module.

[0051] The hydropower digital twin model construction module is used to aggregate and model reservoir power stations and surface photovoltaic power plants in the reservoir group into a virtual power plant, thereby constructing a digital twin model of distributed hydropower. Through digital technology, the module deeply integrates reservoir power stations and surface photovoltaic power plants in the reservoir group, aggregates and models them into a virtual power plant, and constructs a digital twin model of distributed hydropower to realize the monitoring of power generation status in the virtual scene.

[0052] In one possible design, the hydropower digital twin model building module:

[0053] The reservoir power stations and surface photovoltaic power plants within the reservoir group are aggregated and modeled as virtual power plants, connecting the power generation of the reservoir power stations and the surface photovoltaic power plants to form a collaborative scheduling system. A 3D modeling technology is used to create a 3D model of the reservoir group, constructing a digital twin model of distributed hydropower. The reservoir group is divided into monitoring sub-regions according to an equal area division method, and each monitoring sub-region is sequentially numbered 1, 2, ... i, ... n, and associated with the digital twin model.

[0054] Please see Figure 2 As shown, the distributed power data acquisition module is used to collect distributed power data from each monitoring sub-area of ​​the reservoir group. The distributed power data acquisition module includes a generator power generation data acquisition unit and a photovoltaic power generation data acquisition unit. The distributed power data includes generator power generation data and photovoltaic power generation data.

[0055] In one possible design, the distributed power data acquisition module specifically comprises:

[0056] The generator set data acquisition unit collects the turbine inlet water level, turbine outlet water level, and turbine power output for each monitoring sub-area of ​​the reservoir group, and marks them as follows: , , , where i=1,2,...n, i represents the number of the i-th monitoring sub-region, which is associated with the digital twin model;

[0057] Photovoltaic power generation data acquisition unit: Collects the upper limit of energy storage charging and discharging power, rated power of surface photovoltaic installations, rated energy storage capacity, and average daily photovoltaic power generation for each monitoring sub-area of ​​the reservoir group, and marks them as follows: , , , It is associated with the digital twin model.

[0058] The generator set regulation module is used to receive distributed power data transmitted by the distributed power data acquisition module, calculate the reservoir capacity dispatchability index of each monitoring sub-region of the reservoir group based on the generator set power data acquisition unit, and divide the regulation measures for different generator set operating areas. The reservoir capacity dispatchability index is used to determine the unit efficiency of different sub-regions, and combined with the turbine flow rate, the stability of the operation of high-efficiency generator sets in the reservoir is maintained, the power output of low-efficiency generator sets in the reservoir is improved, and hydraulic losses are reduced.

[0059] In one possible design, the generator set regulation module specifically comprises:

[0060] Step S01: Based on the turbine inlet water level, turbine outlet water level, and turbine power generation output, calculate the reservoir capacity dispatchability index of each monitoring sub-region of the reservoir group;

[0061] Step S02: Establish the logic for judging the efficient operation zone: When the reservoir unit capacity dispatchability index The preset reservoir capacity dispatchability index and the minimum turbine flow rate. turbine flow rate The maximum value of the turbine flow rate indicates that the reservoir unit in the monitored sub-area is in a high-efficiency operating zone. Increase the inflow rate of the reservoir in the high-efficiency operating zone and correlate it with the digital twin model.

[0062] Step S03: Establish the logic for judging inefficient operating areas: When the reservoir unit capacity dispatchability index The preset reservoir capacity dispatchability index and turbine flow rate The maximum value of the turbine flow rate indicates that the reservoir units in the monitored sub-area are in an inefficient operating zone. The turbine power output of the monitored sub-area is obtained, and the turbine power output range is adjusted to (minimum turbine power output and maximum turbine power output) to reduce the reservoir inflow in the inefficient operating zone. This is then correlated with the digital twin model.

[0063] Step S04: Establish the logic for determining the no-load operation zone: When the reservoir unit's capacity dispatchability index... The preset reservoir capacity dispatchability index and turbine flow rate The minimum flow rate of the turbine indicates that the reservoir units in the monitored sub-area are in an unloaded operating zone. The reservoir units in the monitored sub-area are then shut down and associated with the digital twin model.

[0064] In this embodiment, it should be specifically noted that the formula for calculating the reservoir capacity dispatchability index is as follows:

[0065]

[0066] in, Let be the reservoir capacity dispatchability index for the i-th monitoring sub-region. Let represent the turbine inlet water level in the i-th monitoring sub-region. Let represent the turbine outlet water level in the i-th monitoring sub-region. This represents the allowable difference in water level between the inlet and outlet of the turbine. Let the power output of the turbines in the i-th monitoring sub-region be denoted as . This represents the minimum power output of the water turbine. This represents the allowable difference between the power output of the water turbine and the minimum power output of the water turbine;

[0067] The formula for calculating the preset reservoir unit capacity dispatchability index is as follows:

[0068]

[0069] in, This represents the preset reservoir capacity dispatchability index. The mean value of the reservoir unit capacity dispatchability index is expressed by the formula: , This represents the minimum value of the reservoir unit capacity dispatchability index, where n represents the number of monitoring sub-regions. It is expressed as the error influence coefficient, which is a constant greater than zero.

[0070] The photovoltaic energy storage power generation regulation module is used to receive distributed power data transmitted by the distributed power data acquisition module, calculate the photovoltaic energy storage dispatchability index of each monitoring sub-region of the reservoir group based on the photovoltaic power generation data collected by the photovoltaic power generation data acquisition unit, and call on photovoltaic power generation equipment for energy storage power supply. By processing the photovoltaic power generation data of each monitoring sub-region of the reservoir group, priority photovoltaic power supply areas and photovoltaic energy storage areas are selected, dynamically adapting to power supply demand, reducing redundant energy storage calls, and ensuring the timeliness of emergency energy replenishment through capacity allocation algorithms, while avoiding excessive calls in individual areas that lead to subsequent power supply capacity imbalance, thereby improving the stability and efficiency of power generation scheduling of the reservoir group.

[0071] In one possible design, the photovoltaic energy storage power generation regulation module specifically comprises:

[0072] S01: Based on the upper limit of energy storage charging and discharging power, the rated power of surface photovoltaic installations, the rated capacity of energy storage, and the average daily power generation of photovoltaics, calculate the photovoltaic energy storage dispatchability index of each monitoring sub-region of the reservoir group;

[0073] S02: Obtain photovoltaic output. Calculate the photovoltaic adjustable margin of each monitoring sub-region of the reservoir group by subtracting the maximum photovoltaic output from the photovoltaic output. If the photovoltaic adjustable margin of a certain monitoring sub-region is greater than the preset photovoltaic adjustable margin, it indicates that the monitoring sub-region is a photovoltaic priority power supply area, with a quantity of m. Conversely, it indicates that the monitoring sub-region is a photovoltaic energy storage area, and is associated with the digital twin model.

[0074] S03: Obtain the available photovoltaic energy storage capacity. If the available photovoltaic energy storage capacity is less than the minimum available photovoltaic energy storage capacity, call the photovoltaic power generation equipment on the reservoir surface in the photovoltaic priority power supply area to simultaneously provide energy storage power supply. Calculate the energy storage capacity allocated to the photovoltaic power generation equipment on the reservoir surface in the photovoltaic priority power supply area according to the energy storage capacity allocation algorithm, and associate it with the digital twin model.

[0075] In this embodiment, it should be specifically noted that the calculation formula for the photovoltaic energy storage dispatchability index is as follows:

[0076]

[0077] in, Let be the photovoltaic energy storage dispatchability index for the i-th monitoring sub-region. This represents the upper limit of the energy storage charging and discharging power of the i-th monitoring sub-region. Let represent the rated power of the surface photovoltaic installations in the i-th monitoring sub-region. Let represent the rated energy storage capacity of the i-th monitoring sub-region. Let be the average daily photovoltaic power generation of the i-th monitoring sub-region. , Represented as weighting coefficients, and + =1;

[0078] Specifically, the ratio of the upper limit of energy storage charging and discharging power to the rated power of surface photovoltaic installations reflects whether the power regulation potential and the scale of photovoltaic installations are matched. The greater the matching degree, the greater the dispatchability index of photovoltaic energy storage. The rated capacity of energy storage reflects how much electricity can be stored. The larger the energy storage capacity, the more abandoned electricity can be stored. The average daily power generation of photovoltaics is used to normalize the rated capacity of energy storage. The larger the rated capacity of energy storage, the greater the dispatchability index of photovoltaic energy storage.

[0079] The calculation of the energy storage capacity allocated to the photovoltaic power generation equipment on the reservoir surface within the photovoltaic priority power supply area according to the energy storage capacity allocation algorithm is as follows:

[0080]

[0081] in, Let represent the energy storage capacity allocated to the i-th photovoltaic priority power supply area, and ky represent the total available energy storage in the photovoltaic priority power supply area. Let m represent the dispatchability index of photovoltaic energy storage in the i-th photovoltaic priority power supply area, and m represent the number of photovoltaic priority power supply areas.

[0082] The distributed power load early warning module collects distributed power load data from smart meters in each monitoring sub-area of ​​the reservoir group, assesses the line load rate in each monitoring sub-area of ​​the reservoir group, and prevents power generation from disrupting grid load. Considering the impact of line losses on the load rate, it calculates the load rate to reflect line pressure through multi-source power superposition and provides graded early warnings to improve grid security.

[0083] In one possible design, the distributed power supply load warning module specifically comprises:

[0084] S01: The distributed power load data includes the active power of the distributed power sources in each monitoring sub-region. Reactive power of distributed power sources Active power of the load reactive power of the load ;

[0085] S02: Calculate the actual active power transmitted by the lines in each monitoring sub-area: ;

[0086] S03: Calculate the actual reactive power transmitted by the lines in each monitoring sub-area:

[0087] S04: Calculate the actual apparent power of the lines in each monitoring sub-area:

[0088] S05: Extract the maximum actual apparent power of the reservoir group's power lines. The formula for calculating the power line load rate is: ,

[0089] in, Let represent the line load rate of the i-th monitoring sub-region. This represents the actual apparent power of the line in the i-th monitoring sub-region. This represents the maximum actual apparent power of the line;

[0090] S06: Obtain the line load rate of each monitoring sub-region of the reservoir group and compare it with the preset line load rate. If the line load rate of a certain monitoring sub-region is... If the preset line load rate is too high, it indicates that there is an overload risk in the monitored sub-area, and an immediate power grid load warning should be issued. Conversely, if the preset line load rate is too low, it indicates that the distributed generation dispatching in the monitored sub-area is operating normally and can be correlated with the digital twin model.

[0091] Please see Figure 3 As shown, the present invention provides a distributed generation scheduling method for a reservoir group, comprising the following steps:

[0092] Step S01: Combine the reservoir power stations within the reservoir group with the surface photovoltaic power plants in the reservoir area to form a virtual power plant, and construct a digital twin model of distributed hydropower.

[0093] Step S02: Collect distributed power generation data for each monitoring sub-area of ​​the reservoir group, including generator power generation data and photovoltaic power generation data;

[0094] Step S03: Based on the collected generator power generation data, calculate the reservoir capacity dispatchability index of each monitoring sub-region of the reservoir group, and divide the regulation measures for different unit operating areas;

[0095] Step S04: Based on the collected photovoltaic power generation data, calculate the photovoltaic energy storage dispatchability index of each monitoring sub-area of ​​the reservoir group, and call upon the photovoltaic power generation equipment for energy storage power supply;

[0096] Step S05: Collect distributed power load data from smart meters in each monitoring sub-area of ​​the reservoir group, assess the line load rate in each monitoring sub-area of ​​the reservoir group, and prevent power generation from disrupting grid load.

[0097] In this embodiment, it should be specifically explained that the present invention constructs a digital twin model of distributed hydropower by aggregating and modeling the reservoir power stations and surface photovoltaic power plants within the reservoir group into a virtual power plant. Distributed power source data from each monitoring sub-region of the reservoir group is collected. Based on the power generation data collected by the unit power generation data acquisition unit, the reservoir capacity dispatchability index of each monitoring sub-region of the reservoir group is calculated. Rules for judging high-efficiency operation zones, low-efficiency operation zones, and no-load operation zones are constructed to classify adjustment measures for different unit operation zones. The results are then correlated with the digital twin model. Through digital technology, the reservoir power stations and surface photovoltaic power plants within the reservoir group are deeply integrated and aggregated into a virtual power plant, constructing a digital twin model of distributed hydropower. This enables monitoring of power generation status in the virtual scenario. The unit efficiency in different sub-regions is determined by the reservoir capacity dispatchability index. Combined with turbine flow rate, the stability of high-efficiency units in reservoir power generation is maintained, and the efficiency of low-efficiency units in reservoir power generation is improved. To improve the power output of the generating units and reduce hydraulic losses, the photovoltaic energy storage dispatchability index of each monitoring sub-region of the reservoir group is calculated based on the photovoltaic power generation data collected by the photovoltaic power generation data acquisition unit. Through the photovoltaic adjustability margin, the photovoltaic priority power supply area is selected, and the available photovoltaic energy storage capacity is obtained. If the available photovoltaic energy storage capacity is less than the minimum available photovoltaic energy storage capacity, the photovoltaic power generation equipment on the reservoir surface in the photovoltaic priority power supply area is called to simultaneously provide energy storage power supply. The energy storage capacity allocated to the photovoltaic power generation equipment on the reservoir surface in the photovoltaic priority power supply area is calculated according to the energy storage capacity allocation algorithm and associated with the digital twin model. By processing the photovoltaic power generation data of each monitoring sub-region of the reservoir group, the photovoltaic priority power supply area and photovoltaic energy storage area are selected, dynamically adapting to power supply demand and reducing redundant energy storage calls. The capacity allocation algorithm ensures the timeliness of emergency energy replenishment and avoids excessive calls in individual areas that lead to subsequent power supply capacity imbalance, thereby improving the stability and efficiency of power generation scheduling of the reservoir group.

[0098] Based on the active power, reactive power, and load power of distributed power sources collected by smart meters in each monitoring sub-area of ​​the reservoir group, the line load rate of each monitoring sub-area is assessed and compared with a preset line load rate. If the line load rate of a certain monitoring sub-area is... The preset line load rate indicates that the line load rate of the monitored sub-area is too high and there is an overload risk. The grid load warning should be issued immediately. Conversely, it indicates that the distributed generation dispatch of the monitored sub-area is operating normally. It is associated with the digital twin model, takes into account the impact of line loss on the load rate, calculates the load rate to reflect the line pressure through the superposition of multiple power sources, and issues graded warnings to improve grid security.

[0099] In conclusion, the above description is only a preferred embodiment of the present invention and is not intended to limit the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the protection scope of the present invention.

Claims

1. A distributed generation dispatching system for a reservoir group, characterized in that, include: Hydropower Digital Twin Model Construction Module: This module is used to aggregate and model reservoir power stations and surface photovoltaic power plants within a reservoir group into virtual power plants, thereby constructing a digital twin model of distributed hydropower. Distributed power data acquisition module: used to collect distributed power data from each monitoring sub-area of ​​the reservoir group. The distributed power data acquisition module includes a generator power generation data acquisition unit and a photovoltaic power generation data acquisition unit. The distributed power data includes generator power generation data and photovoltaic power generation data. Unit power generation regulation module: Used to receive distributed power data transmitted by the distributed power data acquisition module, calculate the reservoir capacity dispatchability index of each monitoring sub-area of ​​the reservoir group based on the unit power generation data collected by the unit power generation data acquisition unit, and divide the regulation measures for different unit operation areas. Photovoltaic energy storage power generation regulation module: used to receive distributed power data transmitted by the distributed power data acquisition module, calculate the photovoltaic energy storage dispatchability index of each monitoring sub-area of ​​the reservoir group based on the photovoltaic power generation data collected by the photovoltaic power generation data acquisition unit, and call photovoltaic power generation equipment to perform energy storage power supply; Distributed power load early warning module: Based on the smart meters in each monitoring sub-area of ​​the reservoir group, the distributed power load data is collected to assess the line load rate in each monitoring sub-area of ​​the reservoir group and prevent power generation scheduling grid load. The hydropower digital twin model construction module: The reservoir power stations and surface photovoltaic power plants within the reservoir group are aggregated and modeled as virtual power plants, connecting the power generation of the reservoir power stations and the surface photovoltaic power plants to form a collaborative scheduling system. A 3D modeling technology is used to create a 3D model of the reservoir group, constructing a digital twin model of distributed hydropower. The reservoir group is divided into monitoring sub-regions according to an equal area division method, and each monitoring sub-region is sequentially numbered 1, 2, ... i, ... n, and associated with the digital twin model. The generator set power generation regulation module is specifically: Step S41: Based on the turbine inlet water level, turbine outlet water level, and turbine power generation output, calculate the reservoir capacity dispatchability index of each monitoring sub-region of the reservoir group; Step S42: Establish the logic for judging the efficient operation zone: When the reservoir unit capacity dispatchability index The preset reservoir capacity dispatchability index and the minimum turbine flow rate. turbine flow rate The maximum value of the turbine flow rate indicates that the reservoir unit in the monitored sub-area is in a high-efficiency operating zone. Increase the inflow rate of the reservoir in the high-efficiency operating zone and correlate it with the digital twin model. Step S43: Establish the logic for judging inefficient operating areas: When the reservoir unit capacity dispatchability index The preset reservoir capacity dispatchability index and turbine flow rate The maximum value of the turbine flow rate indicates that the reservoir units in the monitored sub-area are in an inefficient operating zone. The turbine power output of the monitored sub-area is obtained, and the turbine power output range is adjusted to (minimum turbine power output and maximum turbine power output) to reduce the reservoir inflow in the inefficient operating zone. This is then correlated with the digital twin model. Step S44: Establish the logic for determining the no-load operation zone: When the reservoir unit's capacity dispatchability index... The preset reservoir capacity dispatchability index and turbine flow rate The minimum flow rate of the turbine indicates that the reservoir units in the monitored sub-area are in an unloaded operating zone. The reservoir units in the monitored sub-area are then shut down and associated with the digital twin model.

2. The distributed generation dispatching system for a reservoir group according to claim 1, characterized in that: The distributed power source data acquisition module is specifically: The generator set data acquisition unit collects the turbine inlet water level, turbine outlet water level, and turbine power output for each monitoring sub-area of ​​the reservoir group, and marks them as follows: , where i=1,2,...n, i represents the number of the i-th monitoring sub-region, which is associated with the digital twin model; Photovoltaic power generation data acquisition unit: Collects the upper limit of energy storage charging and discharging power, rated power of surface photovoltaic installations, rated energy storage capacity, and average daily photovoltaic power generation for each monitoring sub-area of ​​the reservoir group, and marks them as follows: , , , It is associated with the digital twin model.

3. A distributed generation dispatching system for a reservoir group according to claim 1, characterized in that: The photovoltaic energy storage power generation regulation module is specifically as follows: S51: Based on the upper limit of energy storage charging and discharging power, the rated power of surface photovoltaic installations, the rated capacity of energy storage, and the average daily power generation of photovoltaics, calculate the photovoltaic energy storage dispatchability index of each monitoring sub-region of the reservoir group; S52: Obtain photovoltaic output. Calculate the photovoltaic adjustable margin of each monitoring sub-region of the reservoir group by subtracting the maximum photovoltaic output value from the photovoltaic output value. If the photovoltaic adjustable margin of a certain monitoring sub-region is greater than the preset photovoltaic adjustable margin, it indicates that the monitoring sub-region is a photovoltaic priority power supply area, with a quantity of m. Conversely, it indicates that the monitoring sub-region is a photovoltaic energy storage area, and is associated with the digital twin model.

4. A distributed generation dispatching system for a reservoir group according to claim 3, characterized in that: The specific steps of using photovoltaic power generation equipment for energy storage and power supply are as follows: Obtain the available capacity of photovoltaic energy storage. If the available capacity of photovoltaic energy storage is less than the minimum available capacity of photovoltaic energy storage, call on the photovoltaic power generation equipment on the water surface of the reservoir in the photovoltaic priority power supply area to simultaneously provide energy storage power supply. Calculate the energy storage capacity allocated to the photovoltaic power generation equipment on the water surface of the reservoir in the photovoltaic priority power supply area according to the energy storage capacity allocation algorithm, and associate it with the digital twin model. The formula for calculating the photovoltaic energy storage dispatchability index is as follows: ； in, Let be the photovoltaic energy storage dispatchability index for the i-th monitoring sub-region. This represents the upper limit of the energy storage charging and discharging power of the i-th monitoring sub-region. Let represent the rated power of the surface photovoltaic installations in the i-th monitoring sub-region. Let represent the rated energy storage capacity of the i-th monitoring sub-region. Let be the average daily photovoltaic power generation of the i-th monitoring sub-region. , Represented as weighting coefficients, and ; The calculation of the energy storage capacity allocated to the photovoltaic power generation equipment on the reservoir surface within the photovoltaic priority power supply area according to the energy storage capacity allocation algorithm is as follows: ； in, Let represent the energy storage capacity allocated to the i-th photovoltaic priority power supply area, and ky represent the total available energy storage in the photovoltaic priority power supply area. Let m represent the dispatchability index of photovoltaic energy storage in the i-th photovoltaic priority power supply area, and m represent the number of photovoltaic priority power supply areas.

5. A distributed generation dispatching system for a reservoir group according to claim 1, characterized in that: The distributed power supply load early warning module is specifically as follows: S71: The distributed power load data includes the active power of the distributed power sources in each monitoring sub-region. Reactive power of distributed power sources Active power of the load reactive power of the load ; S72: Calculate the actual active power transmitted by the lines in each monitoring sub-area: ; S73: Calculate the actual reactive power transmitted by the lines in each monitoring sub-area: ; S74: Calculate the actual apparent power of the lines in each monitoring sub-region: ; S75: Extract the maximum actual apparent power of the reservoir group's power lines. The formula for calculating the power line load rate is: , in, Let represent the line load rate of the i-th monitoring sub-region. Let represent the actual apparent power of the line in the i-th monitoring sub-region. This represents the maximum actual apparent power of the line; S76: Obtain the line load rate of each monitoring sub-region of the reservoir group and compare it with the preset line load rate. If the line load rate of a certain monitoring sub-region... If the preset line load rate is too high, it indicates that there is an overload risk in the monitored sub-area, and an immediate power grid load warning should be issued. Conversely, if the preset line load rate is too low, it indicates that the distributed generation dispatching in the monitored sub-area is operating normally and can be correlated with the digital twin model.

6. A method for dispatching distributed generation in a reservoir group, using a distributed generation dispatching system for a reservoir group as described in any one of claims 1-5, characterized in that: Includes the following steps: Step S01: Combine the reservoir power stations within the reservoir group with the surface photovoltaic power plants in the reservoir area to form a virtual power plant, and construct a digital twin model of distributed hydropower. Step S02: Collect distributed power generation data for each monitoring sub-area of ​​the reservoir group, including generator power generation data and photovoltaic power generation data; Step S03: Based on the collected generator power generation data, calculate the reservoir capacity dispatchability index of each monitoring sub-region of the reservoir group, and divide the regulation measures for different unit operating areas; Step S04: Based on the collected photovoltaic power generation data, calculate the photovoltaic energy storage dispatchability index of each monitoring sub-area of ​​the reservoir group, and call upon the photovoltaic power generation equipment for energy storage power supply; Step S05: Collect distributed power load data from smart meters in each monitoring sub-area of ​​the reservoir group, assess the line load rate in each monitoring sub-area of ​​the reservoir group, and prevent power generation from disrupting grid load.

Images