An active power regulation method for a water power, photovoltaic, and energy storage power complementary integrated power supply

Abstract

This invention discloses an active power regulation method for an integrated power source that complements hydropower, photovoltaic (PV), and energy storage. The complementary integrated unit performs the following adjustments based on acquired parameters: calculating the charge / discharge correction power of the energy storage unit; calculating the target active power value of the hydropower unit; calculating the primary frequency regulation coefficient of the hydropower unit; generating start-up and shutdown suggestions for the PV unit; and calculating and allocating the target active power value of the energy storage unit. This invention uses hydropower to compensate and regulate the PV power source, and energy storage to compensate and regulate both the hydropower and PV power units. It utilizes a power source with better regulation performance to compensate and regulate a power source with poorer regulation performance or no regulation capability. For PV power sources that lack primary frequency regulation capability but must undertake primary frequency regulation obligations as power generators, a control strategy is adopted to transfer all primary frequency regulation tasks to the hydropower source.

Description

Technical Field

[0001] This invention belongs to the field of power system automation control technology, and relates to an active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage power sources. Background Technology

[0002] With the implementation of the new energy strategy, the proportion of photovoltaic power generation is constantly increasing. However, photovoltaic power generation is mainly dependent on the weather, and its power generation capacity is strongly dependent on non-adjustable and non-storable meteorological resources. It has strong randomness and volatility characteristics, which seriously threatens the safety of the power grid.

[0003] Hydropower uses the potential energy of water as the power source for generators, thus having better adjustability and storage capacity (depending on reservoir capacity) compared to photovoltaic power generation. Together with thermal power, it is the core supporting power source of the power system to date.

[0004] The imbalance between power generation and power consumption in the power grid manifests as a deviation between the grid frequency and the rated frequency (50Hz). When the deviation exceeds a threshold, the dispatching agency adjusts the output active power of each grid-connected power station within its control range to restore the balance between power generation and power consumption, ensuring that the difference between the grid frequency and the rated frequency remains within acceptable limits. This entire process is called secondary frequency regulation. Secondary frequency regulation includes the following steps: 1) The dispatching agency calculates the change in power generation required to restore the grid frequency to the rated frequency based on the grid frequency deviation and the grid's "frequency-power" sensitivity coefficient; 2) The dispatching agency corrects the active power setpoints of each grid-connected power station within its control area based on the calculation results and issues power regulation commands; 3) After receiving the new active power setpoints, each power station uses AGC to distribute the total active power setpoints of the power station to each unit controlled by the AGC; 4) The active power control system of each unit performs closed-loop feedback regulation of the unit's active power based on the new individual unit active power setpoints.

[0005] When the deviation between the grid frequency and the rated frequency exceeds the primary frequency regulation threshold (0.05Hz for hydropower in most domestic power grids), the governor systems of each generating unit adjust the active power of the unit according to the preset "frequency-power" adjustment coefficient to compensate for the imbalance between the grid's generating power and power consumption to a certain extent. Compared with secondary frequency regulation, primary frequency regulation cannot completely restore the grid frequency to the rated frequency because there is no unified control center to coordinate and control the generating units participating in primary frequency regulation, and it is related to the calculation mechanism of the adjustment amount. Therefore, it is also called differential regulation. However, the advantages of primary frequency regulation are: 1) Since there is no unified control center, the risk of complete failure like that of secondary frequency regulation (such as the abnormal exit of the scheduling secondary frequency regulation function module) is avoided, thus achieving extremely high overall reliability; 2) The adjustment command is directly calculated by the generating unit, omitting the scheduling calculation, command transmission, and power station AGC allocation processes of secondary frequency regulation. Therefore, the response speed to grid frequency anomalies is much faster than that of secondary frequency regulation. Summary of the Invention

[0006] The technical problem solved by this invention is to provide an active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage. This method utilizes a power source with better regulation performance to compensate for and regulate a power source with poorer regulation performance or no regulation capability, thereby improving the overall active power regulation performance of the complementary integrated power source.

[0007] This invention is achieved through the following technical solution:

[0008] A method for regulating the active power of an integrated power source that complements hydropower, photovoltaic, and energy storage power sources, wherein the integrated power source control center coordinates and controls the hydropower source, energy storage power source, and photovoltaic energy source. The integrated power source control center is equipped with a complementary integration unit, a hydropower source unit, an energy storage power source unit, and a photovoltaic power source unit.

[0009] The hydropower unit obtains intermediate control parameters for the hydropower source based on the basic parameters of the hydropower source and sends them to the complementary integration unit; the energy storage unit obtains intermediate control parameters for the energy storage source, including battery status and energy storage regulation coefficient, based on the basic parameters of the energy storage source and sends them to the complementary integration unit; the photovoltaic power unit sends intermediate control parameters for the photovoltaic source to the complementary integration unit.

[0010] The complementary integration unit performs the following adjustments based on the acquired parameters:

[0011] S100) Calculate the charge / discharge correction power of the energy storage power unit: Wherein, α is the charge-discharge coefficient, which is updated at fixed intervals based on the overall battery charge status of the energy storage power unit. and These are the maximum and minimum battery charge values ​​for energy storage unit i, respectively.

[0012] S200) Calculate the target value of the unit active power of the hydropower source. The target value of the unit active power of the hydropower source is equal to the total active power set value of the complementary integrated power source minus the filter value of the actual active power of the photovoltaic power source unit, plus the charge and discharge correction power of the energy storage power source unit. The filter value of the actual active power of the photovoltaic power source unit is updated at a fixed period based on the actual active power of the photovoltaic power source unit, the filter threshold, and the output dead zone of the photovoltaic power source unit.

[0013] Calculate the primary frequency regulation coefficient of the hydropower unit. The primary frequency regulation coefficient of the hydropower unit is the primary frequency regulation coefficient of the hydropower unit issued by the grid multiplied by the primary frequency regulation scaling factor. The primary frequency regulation scaling factor is equal to (rated active power capacity of the photovoltaic power unit + rated active power capacity of the hydropower unit) ÷ rated active power capacity of the hydropower unit. Each unit of the hydropower unit performs the primary frequency regulation task according to the primary frequency regulation coefficient.

[0014] S210) Compare the target value of the unit active power of the hydropower source with the unit joint operation area of ​​the hydropower source:

[0015] S211) When the target value of the unit active power is included in the joint operation area of ​​the unit, the target value of the unit active power is feasible; the complementary integrated unit sends the target value of the unit active power and the primary frequency regulation coefficient to the hydraulic power unit, which performs unit-level AGC allocation of the target value of the unit active power of the hydraulic power unit, and performs primary and secondary frequency regulation on the active power of the hydraulic power unit.

[0016] S212) When the target value of the unit's active power is not included in the unit's joint operation zone, and the target value of the unit's active power is not feasible, then find operational suggestions to make the target value of the unit's active power feasible:

[0017] The system sequentially seeks operational suggestions to make the target active power value of the hydropower source unit feasible by putting non-AGC units into AGC control; to make the target active power value of the hydropower source unit feasible by switching non-generating units into generating mode and putting them into AGC; and to make the target active power value of the hydropower source unit feasible by switching generating units into non-generating mode. The found operational suggestions are categorized and displayed in order of priority to generate operational suggestions for the hydropower source unit.

[0018] S300 generates start-up and shutdown recommendations for photovoltaic units:

[0019] After determining the target value of the active power of the hydropower unit, obtain the quantitative value of the mismatch between the current start-up and shutdown status of the photovoltaic power unit and the set value of the total active power of the complementary integrated power in the future time T1.

[0020] Then, the quantified value of the mismatch between the current photovoltaic power unit's start-up and shutdown status and the set value of the total active power of the complementary integrated power supply within the future time T1 is compared with the quantified value of the mismatch between the sequence of possible fluctuations in active power corresponding to the photovoltaic unit's start-up and shutdown sequence and the set value of the total active power of the complementary integrated power supply within the future time T1. Based on the comparison results, operation suggestions are generated, and the generated photovoltaic unit start-up and shutdown operation suggestions are displayed in an orderly manner.

[0021] S400) Calculate the target value of the active power of the energy storage power unit:

[0022] S410) Add the set value of the total active power of the complementary integrated power supply to the unit primary frequency regulation correction of the hydropower unit, then subtract the unit active power actual value of the photovoltaic power unit for calculation, and then subtract the unit active power actual value of the hydropower unit to obtain the total active power regulation deviation of the hydropower unit and the photovoltaic power unit.

[0023] S420) The compensation adjustment amount of the energy storage power unit is initially set to the total active power adjustment deviation, and then the compensation adjustment amount of the energy storage power unit is compared with the current total active power adjustment deviation at a fixed period:

[0024] S421) When the absolute value of the difference between the two is greater than the dead zone of the active power regulation of the energy storage power unit, the compensation regulation amount of the energy storage power unit is equal to the total active power regulation deviation in the current period.

[0025] S422) When the absolute value of the difference between the two is less than or equal to the dead zone of the active power regulation of the energy storage power unit, the compensation regulation amount of the energy storage power unit remains unchanged.

[0026] S430) performs dead-zone processing on the compensation adjustment amount of the energy storage power unit to obtain the target value of the unit active power of the energy storage power unit; the complementary integration unit sends the target value of the unit active power of the energy storage power unit to the energy storage power unit.

[0027] The energy storage power unit obtains the unit active power target value after dead zone processing, performs unit-level AGC allocation, and adjusts the active power of each energy storage unit.

[0028] Compared with the prior art, the present invention has the following beneficial technical effects:

[0029] This invention uses hydropower to compensate and regulate photovoltaic power, and energy storage power to compensate and regulate both hydropower and photovoltaic power units. It utilizes power with better regulation performance to compensate and regulate power with poorer regulation performance or power without regulation capability, thereby improving the overall active power regulation performance of the complementary integrated power supply. For photovoltaic power that does not have primary frequency regulation function but must undertake primary frequency regulation obligation as a power generation source, a control strategy is adopted to transfer all its primary frequency regulation task to hydropower.

[0030] This invention focuses on the emerging energy storage power source, especially the shallow charging and discharging problem of energy storage power batteries. When designing the battery charging and discharging strategy, the charging and discharging correction power is introduced into the active power target value of the hydropower unit, so that the hydropower source is used as the charging and discharging source of the energy storage power battery. At the same time, on the one hand, the battery status of each energy storage unit is introduced as a weight parameter into the calculation of the adjustment coefficient of the energy storage unit. On the other hand, a control strategy is designed to prevent drastic changes in the adjustment coefficient of each energy storage unit, so as to simultaneously take into account the needs of the battery status of each unit and the needs of the dynamic stability of active power during the adjustment process.

[0031] This invention also addresses the non-ideal nature of the regulation process and results caused by delays and accuracy issues in various power supply regulation. It introduces numerous parameters such as computational dead zones into the active power control strategy to suppress the overall sensitivity of the control strategy and prevent problems such as excessively high calculation frequency, frequent changes in regulation targets, and overcompensation. Furthermore, by introducing the actual active power output of photovoltaic power units into the calculation of the filtered value in the complementary integrated power supply, the sensitivity of the hydropower source to random fluctuations in the active power output of photovoltaic power units is reduced. The hydropower source is only responsible for correcting large deviations in the actual active power output of photovoltaic power units and for performing the charging and discharging tasks of the energy storage battery.

[0032] By coordinating the active power control of hydropower, photovoltaic power, and energy storage as an organic whole, with hydropower and photovoltaic power handling the power generation task and hydropower and energy storage power handling the regulation task, the advantages are: 1) Thanks to the cooperation of hydropower and energy storage, it has good primary and secondary frequency regulation performance; 2) During primary and secondary frequency regulation, the energy storage power is only responsible for providing dynamic compensation based on the regulation of the hydropower, thus its regulation amplitude, regulation duration, and directional imbalance are controlled within a small range, allowing for the configuration of smaller battery capacity for the energy storage power, and also making it easier to implement the "shallow charge and shallow discharge" control strategy for the energy storage battery; 3) Thanks to the good resource storage and peak-valley regulation capabilities of hydropower, through reasonable configuration of hydropower... The scale ratio of photovoltaic power sources can greatly reduce the possibility of curtailment of photovoltaic power during off-peak hours. Especially considering the characteristic of photovoltaic power stations that can only generate electricity during the day, the load of hydropower stations can be reduced as much as possible during the day to ensure photovoltaic output, while the output of hydropower stations can be increased at night, thereby ensuring the stable output of the integrated power source throughout the day; 4) Introducing photovoltaic power into the power generation system can reduce the active power output of hydropower in the case of abundant sunshine, thereby achieving energy-saving goals. At the same time, for hydropower stations that do not have multi-year regulation capabilities or seasonal regulation capabilities, since hydropower and photovoltaic power have a certain degree of complementarity in the seasonal output characteristics throughout the year, the introduction of photovoltaic power is also conducive to bridging the gap in power generation capacity of hydropower during the wet and dry seasons, thereby ensuring the stable output of the integrated power source throughout the year to a certain extent. Attached Figure Description

[0033] Figure 1 This is a simulation model diagram of the complementary integrated power supply of "hydraulic power source + photovoltaic power source + energy storage power source" of the present invention;

[0034] Figure 2 This is a diagram of the calculation and control logic framework of the energy storage power unit of the present invention;

[0035] Figure 3 This is a logic flowchart for calculating the adjustment coefficients of each energy storage unit in the energy storage power unit according to the present invention.

[0036] Figure 4 This is a schematic diagram showing the relationship between the effective threshold parameters for upward and downward adjustment of each energy storage unit of the present invention and the battery state-of-charge capacity ratio.

[0037] Figure 5 This is a schematic diagram of the dead-zone processing logic for the active power target value of the energy storage power unit in the complementary integrated power supply of the present invention.

[0038] Figure 6 This is a diagram illustrating the regulation effect of the complementary integrated power supply of "hydraulic power + photovoltaic + energy storage power" of the present invention.

[0039] Figure 7 Simulation modeling of the complementary integrated power supply of "hydraulic power + photovoltaic + energy storage power" of the present invention. Figure 2 ;

[0040] Figure 8 Simulation modeling of the complementary integrated power supply of "hydraulic power + photovoltaic + energy storage power" of the present invention. Figure 2 The adjustment effect diagram. Detailed Implementation

[0041] The present invention will be further described in detail below with reference to embodiments. These descriptions are for illustrative purposes only and are not intended to limit the scope of the invention.

[0042] A method for regulating the active power of an integrated power source that complements hydropower, photovoltaic, and energy storage power sources, wherein the integrated power source control center coordinates and controls the hydropower source, energy storage power source, and photovoltaic energy source. The integrated power source control center is equipped with a complementary integration unit, a hydropower source unit, an energy storage power source unit, and a photovoltaic power source unit.

[0043] The hydropower unit obtains intermediate control parameters for the hydropower source based on the basic parameters of the hydropower source and sends them to the complementary integration unit; the energy storage unit obtains intermediate control parameters for the energy storage source, including battery status and energy storage regulation coefficient, based on the basic parameters of the energy storage source and sends them to the complementary integration unit; the photovoltaic power unit sends intermediate control parameters for the photovoltaic source to the complementary integration unit.

[0044] The complementary integration unit performs the following adjustments based on the acquired parameters:

[0045] S100) Calculate the charge / discharge correction power of the energy storage power unit: Wherein, α is the charge-discharge coefficient, which is updated at fixed intervals based on the overall battery charge status of the energy storage power unit. and These are the maximum and minimum battery charge values ​​for energy storage unit i, respectively.

[0046] S200) Calculate the target value of the unit active power of the hydropower source. The target value of the unit active power of the hydropower source is equal to the total active power set value of the complementary integrated power source minus the filter value of the actual active power of the photovoltaic power source unit, plus the charge and discharge correction power of the energy storage power source unit. The filter value of the actual active power of the photovoltaic power source unit is updated at a fixed period based on the actual active power of the photovoltaic power source unit, the filter threshold, and the output dead zone of the photovoltaic power source unit.

[0047] Calculate the primary frequency regulation coefficient of the hydropower unit. The primary frequency regulation coefficient of the hydropower unit is the primary frequency regulation coefficient of the hydropower unit issued by the grid multiplied by the primary frequency regulation scaling factor. The primary frequency regulation scaling factor is equal to (rated active power capacity of the photovoltaic power unit + rated active power capacity of the hydropower unit) ÷ rated active power capacity of the hydropower unit. Each unit of the hydropower unit performs the primary frequency regulation task according to the primary frequency regulation coefficient.

[0048] S210) Compare the target value of the unit active power of the hydropower source with the unit joint operation area of ​​the hydropower source:

[0049] S211) When the target value of the unit active power is included in the joint operation area of ​​the unit, the target value of the unit active power is feasible; the complementary integrated unit sends the target value of the unit active power and the primary frequency regulation coefficient to the hydraulic power unit, which performs unit-level AGC allocation of the target value of the unit active power of the hydraulic power unit, and performs primary and secondary frequency regulation on the active power of the hydraulic power unit.

[0050] S212) When the target value of the unit's active power is not included in the unit's joint operation zone, and the target value of the unit's active power is not feasible, then find operational suggestions to make the target value of the unit's active power feasible:

[0051] The system sequentially seeks operational suggestions to make the target active power value of the hydropower source unit feasible by putting non-AGC units into AGC control; to make the target active power value of the hydropower source unit feasible by switching non-generating units into generating mode and putting them into AGC; and to make the target active power value of the hydropower source unit feasible by switching generating units into non-generating mode. The found operational suggestions are categorized and displayed in order of priority to generate operational suggestions for the hydropower source unit.

[0052] S300 generates start-up and shutdown recommendations for photovoltaic units:

[0053] After determining the target value of the active power of the hydropower unit, obtain the quantitative value of the mismatch between the current start-up and shutdown status of the photovoltaic power unit and the set value of the total active power of the complementary integrated power in the future time T1.

[0054] Then, the quantified value of the mismatch between the current photovoltaic power unit's start-up and shutdown status and the set value of the total active power of the complementary integrated power supply within the future time T1 is compared with the quantified value of the mismatch between the sequence of possible fluctuations in active power corresponding to the photovoltaic unit's start-up and shutdown sequence and the set value of the total active power of the complementary integrated power supply within the future time T1. Based on the comparison results, operation suggestions are generated, and the generated photovoltaic unit start-up and shutdown operation suggestions are displayed in an orderly manner.

[0055] S400) Calculate the target value of the active power of the energy storage power unit:

[0056] S410) Add the set value of the total active power of the complementary integrated power supply to the unit primary frequency regulation correction of the hydropower unit, then subtract the unit active power actual value of the photovoltaic power unit for calculation, and then subtract the unit active power actual value of the hydropower unit to obtain the total active power regulation deviation of the hydropower unit and the photovoltaic power unit.

[0057] S420) The compensation adjustment amount of the energy storage power unit is initially set to the total active power adjustment deviation, and then the compensation adjustment amount of the energy storage power unit is compared with the current total active power adjustment deviation at a fixed period:

[0058] S421) When the absolute value of the difference between the two is greater than the dead zone of the active power regulation of the energy storage power unit, the compensation regulation amount of the energy storage power unit is equal to the total active power regulation deviation in the current period.

[0059] S422) When the absolute value of the difference between the two is less than or equal to the dead zone of the active power regulation of the energy storage power unit, the compensation regulation amount of the energy storage power unit remains unchanged.

[0060] S430) performs dead-zone processing on the compensation adjustment amount of the energy storage power unit to obtain the target value of the unit active power of the energy storage power unit; the complementary integration unit sends the target value of the unit active power of the energy storage power unit to the energy storage power unit.

[0061] The energy storage power unit obtains the unit active power target value after dead zone processing, performs unit-level AGC allocation, and adjusts the active power of each energy storage unit.

[0062] Each unit will be explained below.

[0063] The parameters acquired by the complementary integration unit (S1000) include:

[0064] Parameters input to the S1100 complementary integrated unit:

[0065] S1111) The total active power setting value of the complementary integrated power supply directly input;

[0066] S1112) Rated active power capacity of unit, where the rated active power capacity of unit of hydropower and photovoltaic power is equal to the sum of the rated active power capacity of the single unit of the power generation unit of this type of power unit, and the rated active power capacity of unit of energy storage power depends on the rated capacity of each energy storage unit and the state of charge of the battery.

[0067] The actual active power generated by unit S1113) is equal to the sum of the actual active power generated by each unit of the hydropower unit, energy storage unit, and photovoltaic power unit.

[0068] The active power regulation dead zone of unit S1114) is equal to the sum of the active power regulation dead zones of the single unit of the hydraulic power unit and the energy storage power unit that are in operation.

[0069] Input parameters sent by the S1120 hydraulic power unit:

[0070] S1121) The unit primary frequency regulation target adjustment of the hydropower unit is equal to the sum of the single unit primary frequency regulation target adjustment of the generating units;

[0071] S1122) Joint operation zone of hydraulic power unit;

[0072] S1123) Actual frequency regulation of the primary frequency regulation of the hydraulic power unit;

[0073] S1124) The unit primary frequency regulation correction amount of the hydraulic power unit is equal to the actual adjustment amount of the unit primary frequency regulation of the hydraulic power unit when the actual adjustment amount of the primary frequency regulation of each unit of the hydraulic power unit can be measured; otherwise, it is equal to the unit primary frequency regulation target adjustment amount of the hydraulic power unit as described in S1121.

[0074] S1130) Parameters sent by the energy storage power unit: The charge and discharge correction power of the energy storage power unit is calculated by the energy storage power unit based on parameters such as the battery status of each energy storage unit.

[0075] Input parameters sent by the S1140 photovoltaic power unit:

[0076] S1141) The actual active power generated by the photovoltaic power unit is included in the calculation. It is calculated by the photovoltaic power unit based on the actual active power generated by the unit and the dead zone of each photovoltaic unit.

[0077] S1142) The actual active power generated by the photovoltaic power unit is used as a filter value in the calculation. It is calculated by the photovoltaic power unit based on the actual active power generated by the unit and the dead zone of each photovoltaic unit.

[0078] S1143) The possible fluctuation range of active power of photovoltaic power unit is a prediction result of the fluctuation range of active power of photovoltaic power unit within a certain period of time in the future.

[0079] S1144) The start-up and shutdown sequences of the photovoltaic power unit, and their corresponding active power fluctuation range sequences, are used to generate start-up and shutdown operation suggestions for the photovoltaic unit.

[0080] S1145) The unit primary frequency regulation target adjustment of a photovoltaic power unit is equal to the sum of the single unit primary frequency regulation target adjustment of a photovoltaic unit that is generating electricity;

[0081] The instructions for starting and stopping the photovoltaic power unit are derived from the total active power setpoint of the complementary integrated power source, the joint operation zone of the hydropower unit, the possible fluctuation range of the active power of the photovoltaic power unit, the start-up and shutdown sequence of the photovoltaic power unit, and the sequence of possible fluctuation ranges of active power corresponding to the start-up and shutdown sequence, and generate start-up and shutdown operation suggestions for photovoltaic units for operators to refer to.

[0082] The operation of the hydraulic power source is described in detail below (S2000).

[0083] S2100) determines the unit type of the hydroelectric power unit, including:

[0084] S2110) Generator sets and non-generator sets are classified according to different unit states, wherein non-generator sets include units in the shutdown state, idling state, no-load state and uncertain state;

[0085] S2120) Based on the different controlled states of active power regulation of the generator set, generator sets are further divided into:

[0086] S2131) Single-unit open-loop unit, that is, a unit whose actual active power generation value is not subject to any source regulation;

[0087] S2132) A single-unit closed-loop unit is a unit whose actual active power output is adjusted in a closed loop according to the set value or execution value of the single-unit active power, so that the actual active power output of the unit continuously approaches the set value or execution value of the single-unit active power, and eventually stabilizes within the dead zone range of the set value or execution value of the single-unit active power.

[0088] S2133) Units that have AGC enabled, i.e., single-unit closed-loop units, and whose single-unit active power setpoint is allocated and set by unit-level AGC.

[0089] S2134) Generator units that have not been put into AGC, that is, generator units other than those put into AGC, including single-unit open-loop generator units and single-unit closed-loop generator units whose single-unit active power setting value does not accept unit-level AGC allocation and setting.

[0090] S2200) Establish a combined output model for each unit with AGC, and calculate the joint operation zone, joint recommended operation zone, and joint restricted operation zone, including:

[0091] S2210) Determines the recommended operating area, restricted operating area, prohibited operating area, and operating area for each AGC unit, including:

[0092] S2211) The single-unit prohibited operation zone refers to the load area in which the set value of the single unit active power is prohibited from being set (between the upper and lower limits of the single-unit prohibited operation zone); the actual value of the single unit active power is allowed to pass through the single-unit prohibited operation zone, but it is not allowed to stay or remain in the single-unit prohibited operation zone for a long time.

[0093] S2212) The recommended operating range for a single unit refers to the load area where the unit operates with high efficiency and stability when the actual active power of the unit is within the range (between the upper and lower limits of the recommended operating range for a single unit). Where conditions permit, the set value of the active power of the unit should be set within the recommended operating range for a single unit.

[0094] S2213) The single-unit restricted operating zone refers to the load area where it is generally not recommended to set the single-unit active power setting value of the unit within the range (between the upper and lower limits of the single-unit restricted operating zone). However, when the total active power setting value of all units cannot be allocated in any way to ensure that the single-unit active power setting value of all units is within the recommended single-unit operating zone, it is also allowed to set the single-unit active power setting value of the unit within the single-unit restricted operating zone.

[0095] S2214) Single-machine operation area, the single-machine recommended operation area described in S2212 and the single-machine restricted operation area described in S2213 are collectively referred to as the single-machine operation area;

[0096] S2216) The range of the single-unit restricted operation zone, single-unit prohibited operation zone, and single-unit recommended operation zone of conventional hydropower units varies with the real-time head changes of the hydropower station and are the unit's conventional operating parameters;

[0097] (S2217) The rated capacity of a single hydropower unit, after deducting the prohibited and restricted operating areas, is the recommended operating area for that unit. The rated capacity of a single hydropower unit varies with the real-time head changes of the hydropower station.

[0098] S2220) Establish a recommended combined output model for units with AGC (Automatic Generation Control) and calculate the joint recommended operating area for units with AGC, including:

[0099] S2221) Based on the rated capacity of each unit, the prohibited operating area of ​​a unit, the restricted operating area of ​​a unit, and the recommended operating area of ​​a unit, the units that have AGC are grouped together. Units with the same parameters are grouped together.

[0100] S2222) For each group of units, based on the distribution of the output of each unit in the recommended operating area of ​​each unit, calculate the group recommended operating area of ​​each group of units under various recommended distribution methods: Based on the number of recommended operating areas of each unit and the number of units in each group, determine various recommended distribution methods, and then calculate the group recommended operating area of ​​each group of units under each recommended distribution method;

[0101] S2223) For all units engaged in AGC, based on the different distribution patterns of each group of units in the single-machine recommended operating area and the corresponding group recommended operating areas of each group of units, calculate the combined recommended operating areas of the AGC-engaged units under various recommended distribution patterns and different combinations of patterns; including: based on the unit grouping results of S2221 and the different distribution patterns of each group of units in the single-machine recommended operating area, list the various combinations of the various recommended distribution patterns of each group of units engaged in AGC as described in S2222, and then calculate the combined recommended operating areas of the AGC-engaged units under each recommended distribution combination;

[0102] S2224) Take the union of the combined recommended operating areas of the AGC units under all recommended distribution combinations obtained in S2223 to obtain the joint recommended operating area of ​​the AGC units.

[0103] S2225) Based on the combined recommended operating areas of the AGC units under various recommended distribution combinations obtained in S2223, determine the available recommended distribution combinations of the AGC units under each output interval within the combined recommended operating area, including: sorting the upper and lower limits of the combined recommended operating area corresponding to each recommended distribution combination obtained in S2223, then dividing the combined recommended operating area of ​​the AGC units obtained in S2224 according to the sorted upper and lower limits to obtain multiple output intervals, and then comparing each output interval with the combined recommended operating areas corresponding to various recommended distribution combinations of the AGC units to obtain the available recommended distribution combinations under each output interval.

[0104] S2230) Establish a limited combined output model for the AGC units and calculate the combined operating range and combined limited operating range of the AGC units, including:

[0105] S2231) Group the units that have been put into AGC according to the method described in S2221;

[0106] S2232) For each group of units, based on the distribution of the output of each unit in each single unit operating area, calculate the group operating area of ​​each group of units under various distribution methods, including: determining various distribution methods based on the number of single unit operating areas and the number of units in each group of units, and then calculating the group operating area of ​​each group of units under each distribution method;

[0107] S2233) For all units with AGC, based on the different distribution patterns of each group of units in the single-machine operating area and the corresponding group operating areas of each group of units, calculate the combined operating areas of the units with AGC under various distribution patterns and different combinations of patterns; including: based on the grouping results of S2231 and the different distribution patterns of each group of units in each single-machine operating area, list the various combinations of the various distribution patterns of each group of units with AGC as described in S2232, and then calculate the combined operating area of ​​the units with AGC under each distribution combination pattern;

[0108] S2234) Calculate the joint operation area and joint restricted operation area of ​​the AGC unit, including: taking the union of the combined operation areas of the AGC unit under all distribution combination modes obtained in S2233 to obtain the joint operation area of ​​the AGC unit, and then subtracting the joint suggested operation area obtained in S2224 from the joint operation area of ​​the AGC unit to obtain the joint restricted operation area of ​​the AGC unit.

[0109] S2235) Based on the combined operating areas of the AGC units under various distribution combinations obtained in S2233, determine the available restricted distribution combination methods for each output interval within the joint restricted operating area, including: sorting the upper and lower limits of the combined operating area corresponding to each distribution combination method obtained in S2233, then dividing the joint restricted operating area of ​​the AGC units obtained in S2234 according to the sorted upper and lower limits to obtain multiple output intervals, and then comparing each output interval with the combined operating area corresponding to various distribution combinations of the AGC units to obtain the available restricted distribution combination methods under each output interval.

[0110] S2240) Determines the current single-unit AGC active power allocation value for each unit, including:

[0111] (S2241) For units with AGC in operation, the active power allocation value of a single unit AGC is allocated by the unit-level AGC.

[0112] S2242) For single-unit closed-loop units without AGC, the active power allocation value of single-unit AGC tracks the active power set value of single unit.

[0113] (S2243) For single-unit open-loop generator sets that have not been put into AGC, the single-unit AGC active power allocation value tracks the single-unit active power set value, while the single-unit active power set value is assigned by the single-unit active power actual value. That is, when the single-unit active power set value is not equal to the single-unit active power actual value, and the absolute value of the difference between the two is greater than the single-unit active power adjustment dead zone, the single-unit active power actual value is written into the single-unit active power set value.

[0114] S2250) The joint recommended operating area of ​​the AGC units obtained from S2220 is added to the active power allocation value of the individual AGC units that are not in use to obtain the joint recommended operating area of ​​the hydraulic power unit, which provides a reference for the automatic control of active power of the hydraulic power unit and the comprehensive control of the complementary integrated power supply.

[0115] S2260) The combined operation zone of the AGC units obtained in S2234 is added to the active power allocation values ​​of the individual AGC units that are not in operation to obtain the combined operation zone of the hydropower unit, which provides a reference for the automatic control of active power of the hydropower unit and the comprehensive control of the complementary integrated power supply.

[0116] S2270) The combined restricted operating area of ​​the AGC units obtained in S2234 is added to the active power allocation values ​​of the individual AGC units that are not in use to obtain the combined restricted operating area of ​​the hydropower unit, which provides a reference for the automatic control of the active power of the hydropower unit.

[0117] (S2300) Compare the target active power value of the hydroelectric power source with the unit joint operation zone described in S2260. If the target active power value is included in the unit joint operation zone, the target active power value is feasible, and the remaining steps of S2300 are skipped; if the target active power value is not included in the unit joint operation zone, the target active power value is infeasible, and an operational suggestion is sought to make the target active power value feasible.

[0118] S2320) Seeking operational recommendations to make the target active power of the hydropower unit feasible by putting units not currently under AGC control into AGC control, including:

[0119] S2321) Set the loop variable i1, and set the initial value of i1 to 1;

[0120] S2322) Determine i1. If i1 is greater than the number of units not in AGC, terminate S2320. Otherwise, continue to execute the following steps to find an operational suggestion to put i1 units not in AGC into AGC control so that the unit active power target value of the hydraulic power source becomes feasible.

[0121] S2323) List all possible combinations of selecting i1 units from all units that have not been put into AGC, for a total of C(j1,i1) combinations, where C() is the combination number function and j1 is the number of units that have not been put into AGC.

[0122] S2324) According to the C(j1,i1) combination methods listed in S2323, the units that have not been put into AGC are assumed to be put into AGC in each method, and the unit joint operation area and the unit joint recommended operation area are recalculated using the S2200 method. Then, based on the newly calculated unit joint operation area, the feasibility of the unit active power target value is reassessed using the S2300 method.

[0123] (S2325) Based on the calculation results of S2324, if there is one and only one way to regenerate the unit joint operation area that makes the unit active power target value feasible, then generate the operation suggestion "put the units selected by this method that have not been put into AGC into AGC". If there are multiple ways to regenerate the unit joint operation area that make the unit active power target value feasible, then generate the operation suggestion "put the units selected by the corresponding method that have not been put into AGC into AGC" according to these methods respectively, and jump to step S2326 to continue execution. If there is no way to regenerate the unit joint operation area that makes the unit active power target value feasible, then i1 = i1 + 1, and then jump to step S2322 to judge whether i1 is greater than the number of units that have not been put into AGC, and decide whether to execute the subsequent steps based on the judgment result.

[0124] S2326) Prioritize the multiple operation suggestions generated in S2325. The ranking is based on the changed unit joint operation area and unit joint suggested operation area range corresponding to these operation suggestions. The ranking criteria are as follows, from highest to lowest importance: whether the unit active power target value belongs to the unit joint suggested operation area (yes is better than no), and the absolute value of the difference between the unit active power target value and the boundary or segment boundary of the unit joint operation area (the larger the better).

[0125] S2330) Seeking operational recommendations to make the target active power of the hydropower unit feasible by converting non-generating units to generating mode and engaging AGC, including:

[0126] S2331) Set the loop variable i2, and set the initial value of i2 to 1;

[0127] S2332) Determine i2. If i2 is greater than the number of available but not generating units, terminate S2330. Otherwise, continue to execute the following steps to find an operational suggestion to convert i2 available but not generating units into generating state and put them into AGC so that the unit active power target value of the hydropower source becomes feasible.

[0128] S2333) List all possible combinations of selecting i2 units from all available but not generating units, totaling C(j2,i2) combinations, where j2 is the number of available but not generating units;

[0129] S2334) According to the C(j2,i2) combination methods listed in S2333, the available but non-generating units selected by each method are assumed to be generating units and put into AGC. The unit joint operation area and the unit joint recommended operation area are recalculated using the S2200 method. Then, based on the newly calculated unit joint operation area, the feasibility of the unit active power target value is reassessed using the S2300 method.

[0130] (S2335) Based on the calculation results of S2334, if there is one and only one way to regenerate the unit joint operation area that makes the unit active power target value feasible, then generate the operation suggestion "convert the available but non-generating units selected by this method into generating state and put them into AGC". If there are multiple ways to regenerate the unit joint operation area that make the unit active power target value feasible, then generate operation suggestions according to these methods respectively "convert the available but non-generating units selected by the corresponding method into generating state and put them into AGC", and jump to step S2336 to continue execution. If there is no way to regenerate the unit joint operation area that makes the unit active power target value feasible, then i2 = i2 + 1, and then jump to step S2332 to judge whether i2 is greater than the number of available but non-generating units, and decide whether to execute the subsequent steps based on the judgment result.

[0131] S2336) Prioritize the multiple operation suggestions generated in S2335. The ranking is based on the changed unit joint operation area and unit joint suggested operation area range corresponding to these operation suggestions. The ranking criteria are as follows, from highest to lowest importance: whether the unit active power target value belongs to the unit joint suggested operation area (yes is better than no), and the absolute value of the difference between the unit active power target value and the boundary or segment boundary of the unit joint operation area (the larger the better).

[0132] S2340) Seeking operational recommendations to make the target active power of the hydroelectric power source unit feasible by switching the generating unit to a non-generating state, including:

[0133] S2341) Set the loop variable i3, and set the initial value of i3 to 1;

[0134] S2342) Determine i3. If i3 is greater than the number of generating units, terminate S2340. Otherwise, continue to execute the following steps to find an operational suggestion to convert i3 generating units to non-generating state so that the unit active power target value of the hydropower source becomes feasible.

[0135] S2343) List all possible combinations of selecting i3 units from all generating units, totaling C(j3,i3) combinations, where j3 is the number of generating units;

[0136] S2344) According to the C(j3,i3) combination methods listed in S2343, the generating units selected in each method are assumed to be in a non-generating state, and the unit joint operation area and unit joint recommended operation area are recalculated using the S2200 method. Then, based on the newly calculated unit joint operation area, the feasibility of the unit active power target value is reassessed using the S2300 method.

[0137] (S2345) Based on the calculation results of S2344, if there is one and only one way to regenerate the unit joint operation area that makes the unit active power target value feasible, then generate the operation suggestion "convert the generating unit selected by this method to non-generating state". If there are multiple ways to regenerate the unit joint operation area that make the unit active power target value feasible, then generate the operation suggestion "convert the generating unit selected by the corresponding method to non-generating state" according to these methods respectively, and jump to step S2346 to continue execution. If there is no way to regenerate the unit joint operation area that makes the unit active power target value feasible, then i3 = i3 + 1, and then jump to step S2342 to judge whether i3 is greater than the number of generating units, and decide whether to execute the subsequent steps based on the judgment result.

[0138] S2346) Prioritizes the multiple operation suggestions generated in S2345. The priority is based on the combination of i3 generating units selected from the generating units for each operation suggestion, and the changed unit joint operation area and unit joint suggested operation area range corresponding to each operation suggestion obtained in S2344. The priority criteria are as follows, from highest to lowest importance: the number of units without AGC (the more the better) and units with AGC (the fewer the better), whether the unit active power target value belongs to the unit joint suggested operation area (yes is better than no), and the absolute value of the difference between the unit active power target value and the boundary or segment boundary of the unit joint operation area (the larger the better).

[0139] S2350) classifies the operation suggestions generated by S2320, S2330, and S2340, and displays them in an orderly manner according to the priority obtained by S2326, S2336, and S2346 (when there is more than one operation suggestion of a certain type) to assist operators in decision-making.

[0140] S2400) calculates the active power allocation value of a single AGC unit in the AGC unit, including:

[0141] S2410) Calculate the unit AGC active power allocation value of the hydraulic power source, including:

[0142] S2411) Calculate the active power allocation value of each AGC unit that is not put into operation. The method for obtaining the active power allocation value of each AGC unit is as described in S2240.

[0143] S2412) Subtract the individual AGC active power allocation values ​​of all AGC units that have not been put into operation from the unit active power target value to obtain the unit AGC active power allocation value.

[0144] S2420) When certain conditions are met, the unit-level AGC allocation process for the hydraulic power source is initiated. The triggering conditions include:

[0145] S2421) The sum of the active power allocation values ​​of the individual AGC units of all AGC units is not equal to (greater than or less than) the active power allocation value of the unit AGC obtained in S2410;

[0146] S2422) The combined output model or joint operation zone, joint recommended operation zone, and joint restricted operation zone of the AGC unit have changed;

[0147] S2423) Units that have engaged AGC are deactivated from unit-level AGC, or units that have not engaged AGC are activated to engage unit-level AGC;

[0148] (S2424) Hydropower units with AGC (Automatic Generation Control) may experience changes in their rated active power capacity, prohibited operating area, restricted operating area, and recommended operating area due to changes in the hydropower station's head.

[0149] S2430) Determine the target distribution combination of the AGC units to be put into operation, including:

[0150] S2431) If the active power allocation value of the unit AGC obtained in S2410 is within the joint recommended operating area of ​​the AGC unit, then based on the available recommended distribution combination methods of the AGC unit under each output range in the joint recommended operating area obtained in S2225, determine all the recommended distribution combination methods of the AGC unit that can satisfy the active power allocation value of the unit AGC and use them as available distribution combination methods; otherwise, based on the available restricted distribution combination methods of the AGC unit under each output range in the joint restricted operating area obtained in S2235, determine all the restricted distribution combination methods of the AGC unit that can satisfy the active power allocation value of the unit AGC and use them as available distribution combination methods.

[0151] S2432) Select the combination with the fewest units in the single-unit restricted operation zone from all available distribution combinations obtained in S2431, and use it as the available distribution combination.

[0152] (S2433) If there are more than one available distribution combination method obtained in S2432, then it is further compared with the current distribution combination method, and the distribution combination method with the fewest number of units crossing the single unit prohibited operation zone is selected as the target distribution combination method. If there are multiple distribution combination methods with the same number of units crossing the single unit prohibited operation zone, then all of them are selected as the target distribution combination methods.

[0153] S2440) Determine the target output combination mode for the AGC unit, including:

[0154] S2441) List all output combinations that can satisfy the target distribution combination obtained in S2430 when the AGC unit is put into operation;

[0155] S2442) Compare all the output combinations listed in S2441 with the current operating area of ​​each unit in AGC, and select the output combination with the fewest number of times the unit crosses the single unit prohibited operating area as the target output combination.

[0156] S2443) If there are more than one target output combination method obtained from S2442, the target output combination methods obtained from S2442 are weighted and applied to the adverse operating condition priority of the AGC unit. The weighting method is to sum the adverse operating condition priorities of each unit in the restricted operating area, and select the output combination method with the fewest weighted units in the single-unit restricted operating area as the target output combination method. The adverse operating condition priority of the unit can be set manually or automatically. When the manual setting method is used, the adverse operating condition priority is set manually by the operator. When the automatic setting method is used, the system automatically performs weighted statistics on the operating time of each unit in the restricted operating area and the prohibited operating area since the last maintenance period, sorts the weighted statistics time of each unit, and then sets the automatic priority in order of weighted time from shortest to longest and from highest to lowest.

[0157] S2444) If there are more than one target output combination method obtained from S2443, after weighting the adverse operating conditions of the AGC units, select the output combination method with the fewest weighted units crossing the single-unit prohibited operation zone from the target output combination method obtained from S2443 as the target output combination method.

[0158] S2450) Based on the target output combination method of the AGC units, the active power allocation for each AGC unit is performed, including:

[0159] S2451) Compare the target operating area of ​​each unit with the current operating area under the target output combination mode. For units whose single unit operating area has changed, the original single unit AGC active power allocation value is corrected to the limit value of the upper and lower limits of the target operating area that is closest to the current single unit operating area. Thereafter, the original single unit AGC active power allocation value used in S2452, S2453 and S2454 are all the corrected values.

[0160] S2452) The result of subtracting the sum of the original single-unit AGC active power allocation values ​​of all AGC units put into operation from the AGC active power allocation value of the calculation unit is used as the value to be allocated;

[0161] S2453) If the value to be allocated obtained from S2452 is greater than 0, then calculate the absolute value of the difference between the original single-unit AGC active power allocation value of each AGC unit and the upper limit of the target operating area, and use it as the single-unit allocable value. If the value to be allocated obtained from S2452 is less than 0, then calculate the absolute value of the difference between the single-unit AGC active power allocation value of each AGC unit and the lower limit of the target operating area, and use it as the single-unit allocable value.

[0162] S2454) The value to be allocated obtained in S2452 is allocated to each AGC unit in a manner that is proportional to the single-unit allocable value of each AGC unit obtained in S2453. The allocation result is then superimposed on the original single-unit AGC active power allocation value of each unit to obtain the single-unit AGC active power allocation value of each AGC unit.

[0163] S2500) Hydropower Unit's active power regulation for each individual closed-loop generator unit includes:

[0164] S2510) Determine the active power setpoint for each individual closed-loop generator unit, including:

[0165] (S2511) For single-unit closed-loop generator units that have not been put into AGC, the active power setting value of a single unit shall be manually set by the operator.

[0166] (S2512) For hydropower units with AGC (Automatic Generation Control) enabled, the active power setting value for a single unit is equal to the active power allocation value for the single unit with AGC.

[0167] The active power control system of each closed-loop unit in the S2530 hydraulic power unit uses the set value of active power of a single unit as the target, calculates the deviation between the actual active power generated by a single unit and the set value of active power of a single unit, and outputs a continuous signal to adjust the actual active power generated by the unit based on the calculation result, so that the actual active power generated by the unit tends to the set value of active power of the single unit, and finally stabilizes within the adjustment dead zone range of the set value of active power of the single unit.

[0168] The operation of the energy storage power unit (S3000) is described below, including its calculation and control logic as follows: Figure 2 As shown, it includes:

[0169] S3100) calculates the capacity ratio of each energy storage unit's battery charge and the overall capacity ratio of the energy storage power unit's battery charge, including:

[0170] S3110) Calculate the battery charge ratio of each energy storage unit. In the formula r i The state-of-charge (SOC) ratio of the batteries in energy storage unit i. i The state of charge of the battery in energy storage unit i. and These represent the maximum and minimum battery charge values ​​for energy storage unit i, respectively. For example, when the SOC of a certain energy storage unit is... i =50, and If they are 100 and 10 respectively, then

[0171] S3120) Calculate the overall capacity ratio of the battery charge in the energy storage power unit. In the formula, r represents the overall capacity ratio of the battery charge of the energy storage power unit. For example, if an energy storage power unit contains 3 energy storage units with battery states of charge (SOCs) of 40%, 50%, and 60%, respectively, the maximum SOCs are 100%, 110%, and 120%, respectively, and the minimum SOCs are 0%, 5%, and 10%, then...

[0172] S3200) Set the threshold values ​​R1' to R6' for the overall capacity ratio of the battery state of charge of the energy storage power unit. The setting principles include:

[0173] S3210)0<R1'<R2'<R3'<R4'<R5'<R6'<1;

[0174] S3220)R1'+R6'=1;

[0175] S3230)R2'+R5'=1;

[0176] S3230)R3'+R4'=1.

[0177] In this embodiment, R1' to R6' are set to 20%, 30%, 45%, 55%, 70%, and 80%, respectively.

[0178] S3300) determines the overall battery state of the energy storage power unit, including:

[0179] S3310) When the overall capacity ratio of the battery charge of the energy storage power unit obtained in S3120 is 0≤r<R1', the overall battery charge of the energy storage power unit is in an extremely low state.

[0180] (S3320) When R1'≤r<R2', the battery of the energy storage power unit is generally in a low charge state;

[0181] (S3330) When R2'≤r<R3' or R4'<r≤R5', the battery of the energy storage power unit is in a relatively ideal state of charge.

[0182] (S3340) When R3'≤r≤R4', the battery of the energy storage power unit is in an ideal state of charge.

[0183] (S3350) When R5'<r≤R6', the battery of the energy storage power unit is generally in a high charge state;

[0184] (S3360) When R6'<r≤1, the battery of the energy storage power unit is in an extremely high charge state.

[0185] S3400) Set the threshold values ​​R1 to R4 for judging the state-of-charge capacity ratio of the energy storage unit's battery. The setting principles include:

[0186] S3210)0<R1<R2<R3<R4<1;

[0187] S3220)R1+R4=1;

[0188] S3230)R2+R3=1.

[0189] In this embodiment, R1 to R4 are set to 20%, 40%, 60%, and 80%, respectively.

[0190] S3500) sets auxiliary calculation parameters for the regulation coefficients of each energy storage unit in the energy storage power unit, including:

[0191] S3510) Set four threshold parameters K1, K2, K3, and K4, where 0 < K1 < K2 < K3 < K4. In this embodiment, K1 to K4 are set to 0.5, 1, 1.5, and 2, respectively.

[0192] S3520) Set the gradient parameter ΔK for the change of the energy storage unit's regulation coefficient, 0 < ΔK < min[K1,K2-K1,K3-K2,K4-K3], where min[] is the minimum value function. The purpose of setting ΔK is to prevent the dynamic stability of the unit's actual active power from decreasing due to the excessive change of the energy storage unit's regulation coefficient during the regulation process. In this embodiment, ΔK is set to 0.1.

[0193] S3600) calculates the adjustment coefficients of each energy storage unit in the energy storage power unit, such as Figure 3 As shown, it includes:

[0194] S3610) Calculate the upward adjustment coefficient of each energy storage unit in the energy storage power unit, including:

[0195] S3611) Initialize and set the upward adjustment coefficient of each energy storage unit in the energy storage power unit. In the formula For energy storage unit i, the upward adjustment coefficient is denoted as .

[0196] S3612) The upward adjustment coefficient of each energy storage unit is corrected according to a fixed cycle, that is, the subsequent steps are continuously cyclically run according to a fixed cycle.

[0197] S3613) Calculate the effective threshold parameter for upward adjustment of each energy storage unit. When 0≤r i <R1 time When R1≤r i <R2 When R2≤r i When ≤R3 When R3 < r i When ≤R4 When R4 < r i ≤1

[0198] S3614) Comparison and When the absolute value of the difference between the two is less than or equal to ΔK When the absolute value of the difference between the two is greater than ΔK and hour When the absolute value of the difference between the two is greater than ΔK and hour For example, a certain energy storage unit and Originally, both values ​​were equal to 1. During discharge, the battery's charge capacity ratio decreased to between R1 and R2, therefore... It then decreased to 0.5, and so in the following several cycles, They were revised to 0.9, 0.8, 0.7, 0.6, and 0.5 respectively.

[0199] S3620) Calculate the downward adjustment coefficient of each energy storage unit in the energy storage power unit, including:

[0200] S3621) Initialize and set the downward adjustment coefficient of each energy storage unit in the energy storage power unit. In the formula is the downward adjustment coefficient for energy storage unit i;

[0201] S3622) The downward adjustment coefficient of each energy storage unit is corrected according to a fixed cycle, that is, the subsequent steps are continuously cyclically run according to a fixed cycle.

[0202] S3623) Calculate the effective threshold parameters for downward adjustment of each energy storage unit. When 0≤r i <R1 time When R1≤r i <R2 When R2≤r i When ≤R3 When R3 < r i When ≤R4 When R4 < r i ≤1

[0203] S3624) Comparison and When the absolute value of the difference between the two is less than or equal to ΔK When the absolute value of the difference between the two is greater than ΔK and hour When the absolute value of the difference between the two is greater than ΔK and

[0204] In the above embodiments, based on the battery state-of-charge capacity ratio r i The effective threshold parameters for upward and downward adjustment of each energy storage unit Each as Figure 4 As shown, with the increase of the battery's state of charge (SOC) ratio, the upward adjustment threshold parameter of the energy storage unit increases, while the downward adjustment threshold parameter decreases. Since the upward and downward adjustment coefficients of the energy storage unit tend to change with the changes in the upward and downward adjustment threshold parameters, the upward and downward adjustment coefficients of the energy storage unit also increase and decrease with the increase of the battery's SOC ratio, respectively.

[0205] S3700 performs unit-level AGC allocation of the target active power value of the energy storage power unit, including:

[0206] S3710) When the target value of the active power of the energy storage power unit is equal to 0, the set value of the active power of each energy storage unit is equal to 0.

[0207] (S3720) When the target active power of the energy storage power unit is greater than 0, the setpoint of the single active power of each energy storage unit is allocated according to the ratio of the product of the upward adjustment coefficient of each energy storage unit and the battery capacity, that is, the setpoint of the single active power of the energy storage unit is equal to... In the formula The target active power of the energy storage power unit is set as follows: If the calculated result is greater than the rated active power capacity of the energy storage unit's forward single unit, then the rated active power capacity of the energy storage unit's forward single unit is used as the set value for the single unit's active power. Assuming the target active power of the energy storage power unit is 300MW and there are 3 energy storage units... The battery capacities are 0.5, 1, and 1.5 respectively. With capacities of 200, 150, and 220 MW respectively, the setpoint active power of each of the three energy storage units is as follows:

[0208] (S3730) When the target active power of the energy storage power unit is less than 0, the setpoint of the active power of each energy storage unit is allocated proportionally to the product of the downward adjustment coefficient of each energy storage unit and the battery capacity. That is, the setpoint of the active power of each energy storage unit is equal to... If the calculated result is less than the rated negative active power capacity of a single energy storage unit, then the rated negative active power capacity of a single energy storage unit will be used as the setpoint for the active power of a single unit. Assuming the target active power of the energy storage power unit is -300MW, and there are 3 energy storage units... The battery capacities are 0.5, 1, and 1.5 respectively. With values ​​of 200, 150, and 220MW respectively, the active power settings for the three energy storage units are -51.7, -77.6, and -170.7MW respectively.

[0209] As described in S3600, the upward adjustment coefficient and downward adjustment coefficient of the energy storage unit increase and decrease respectively as the battery state-of-charge (SOC) ratio increases. Therefore, according to the calculation methods in S3720 and S3730, when the target active power value of the energy storage unit is greater than 0, that is, when the energy storage unit is generally in a discharging state, the energy storage unit with a higher SOC ratio tends to discharge. Conversely, when the target active power value of the energy storage unit is less than 0, that is, when the energy storage unit is generally in a charging state, the energy storage unit with a lower SOC ratio tends to charge. This ensures that the SOC ratio of each energy storage unit remains consistent, thus avoiding overcharging or over-discharging of one or more energy storage units compared to other energy storage units.

[0210] The active power control system of each energy storage unit in the S3800 energy storage power unit uses the set value of active power of a single unit as the target, calculates the deviation between the actual active power generated by a single unit and the set value of active power of a single unit, and outputs a continuous signal to adjust the actual active power generated by a single unit of the energy storage unit according to the calculation result, so that the actual active power generated by a single unit of the energy storage unit tends to the set value of active power of a single unit, and finally stabilizes within the adjustment dead zone range of the set value of active power of a single unit.

[0211] S3900) calculates the rated active power capacity of the energy storage power unit, including:

[0212] S3910) Calculate the upward regulation capability of each energy storage unit in the energy storage power unit, including:

[0213] S3911) When the energy storage unit calculates the effective threshold parameter for upward adjustment as in S3613 At that time, the upward adjustment capability of the unit is equal to the rated active power capacity of the unit in the positive direction.

[0214] S3912) When the energy storage unit calculates the effective threshold parameter for upward adjustment as in S3613 At that time, the upward adjustment capacity of the unit is the rated positive single-unit active power capacity of the unit multiplied by . Divide by K2 again;

[0215] For example, when the rated active power capacity of a single generating unit is 50MW, if K2 = 1, then when When the values ​​are 1.5, 1, and 0.5 respectively, the upward adjustment capacity of the unit is 50, 50, and 25 MW respectively.

[0216] S3920) The upward adjustment energy of each energy storage unit obtained in S3910 is accumulated to obtain the rated active power capacity of the forward unit of the energy storage power unit.

[0217] S3930) Calculates the downregulation capability of each energy storage unit in the energy storage power unit, including:

[0218] S3931) When the energy storage unit calculates the effective threshold parameter for downward adjustment as in S3623 At that time, the downward adjustment capability of the unit is equal to the rated capacity of the negative single unit active power.

[0219] S3932) When the energy storage unit calculates the effective threshold parameter for downward adjustment as in S3623 At that time, the downward regulation capacity of the unit is the rated negative single-unit active power capacity multiplied by [the specified value]. Then divide by K2.

[0220] S3940) The downward regulation energy of each energy storage unit obtained in S3930 is accumulated to obtain the rated capacity of the negative unit active power of the energy storage power unit.

[0221] The operation of the photovoltaic power unit (S4000) is described below, including:

[0222] S4100 addresses the characteristics of photovoltaic power sources, such as non-adjustable active power and fluctuating and intermittent output power. It generates the possible fluctuation range of active power for each unit within a future time period T1 and calculates the possible fluctuation range of unit active power for the photovoltaic power source. T1 is a manually set parameter, designed to allow sufficient time for possible start-up and shutdown operations of the photovoltaic unit, including:

[0223] S4110) If a power prediction system is deployed, the possible fluctuation range of active power of each photovoltaic unit in the future time T1 is output by the power prediction function. The so-called power prediction system refers to a system that uses physical methods, regression methods, time series methods, neural network methods, deep learning methods, etc. to build a prediction model based on past power, historical data of the same period, seasonal changes, weather forecasts, etc., to predict the future active power change trend of photovoltaic power. In order to improve the accuracy and availability of prediction results, the prediction system usually adopts the interval prediction method, that is, predicts the maximum and minimum values ​​that the active power change may reach.

[0224] S4120) If a power prediction system is not deployed, the following methods shall be used, including:

[0225] S4121) For photovoltaic power generation units, the current power multiplied by the upper limit prediction parameter is used as the upper limit of the possible fluctuation range of active power in the future time T1, and the current power multiplied by the lower limit prediction parameter is used as the lower limit of the possible fluctuation range of active power, where the upper limit prediction parameter > 1 > the lower limit prediction parameter > 0.

[0226] S4122) For photovoltaic units that do not generate electricity, the possible fluctuation range of active power in the future T1 time period of a generator unit with the same or similar performance (especially the same single unit capacity) shall be used as the possible fluctuation range of active power in the future T1 time period of the unit.

[0227] (S4123) For the upper limit prediction parameter and lower limit prediction parameter mentioned in S4121, fixed values ​​can be used, or different parameters can be used at different time points. The latter is more suitable for photovoltaic power plants with obvious intra-year and intra-day time patterns. For example, higher prediction parameters are used for a period of time after sunrise, and lower prediction parameters are used for a period of time before sunset.

[0228] S4130) Calculate the possible fluctuation range of the active power of the photovoltaic power unit within the future time period T1, including:

[0229] S4131) The upper limit of the possible fluctuation range of the active power of all generator sets of the photovoltaic power unit within the future time T1 is summed up, which is the upper limit of the possible fluctuation range of the active power of the photovoltaic power unit within the future time T1.

[0230] S4132) The lower limit of the possible fluctuation range of the active power of all generator sets of the photovoltaic power unit within the future time T1 is summed to obtain the lower limit of the possible fluctuation range of the active power of the photovoltaic power unit within the future time T1.

[0231] S4200 generates start-up and shutdown sequences for photovoltaic units, including:

[0232] S4210) Generates a shutdown sequence for photovoltaic power generation units, with priority calculated based on the duration of the unit's power generation state. The longer the unit remains in power generation state, the higher its priority.

[0233] S4220) generates a startup sequence of available but non-generating photovoltaic units. The priority is calculated based on the duration of the unit's non-generating state. The longer the duration of the non-generating state, the higher the priority. The so-called available but non-generating units are in contrast to unavailable units that cannot be switched to generating state due to equipment failure or maintenance work.

[0234] S4300 generates a sequence of possible active power fluctuations corresponding to the start-up and shutdown sequences for each photovoltaic unit, including:

[0235] S4310) This addresses the potential fluctuation range of active power corresponding to the generation and start-up sequence of photovoltaic units:

[0236] S4311) Set variable u1, with an initial value of 1;

[0237] (S4312) Add the possible fluctuation range of active power of the photovoltaic power unit obtained in S4130 to the possible fluctuation range of active power of the unit ranked u1 in the photovoltaic unit start-up sequence to obtain the range of ranked u1 in the possible fluctuation range sequence of active power corresponding to the photovoltaic unit start-up sequence. The upper limit of the range of ranked u1 is equal to the upper limit of the possible fluctuation range of active power of the photovoltaic power unit obtained in S4130 plus the upper limit of the possible fluctuation range of active power of the unit ranked u1 in the photovoltaic unit start-up sequence. The lower limit of the range of ranked u1 is equal to the lower limit of the possible fluctuation range of active power of the photovoltaic power unit obtained in S4130 plus the lower limit of the possible fluctuation range of active power of the unit ranked u1 in the photovoltaic unit start-up sequence.

[0238] S4313) Determine whether u1 is equal to the photovoltaic unit start-up sequence length. If u1 is equal to the photovoltaic unit start-up sequence length, terminate step S4310. Otherwise, execute u1 = u1 + 1 and then continue with the subsequent steps.

[0239] (S4314) The range of active power fluctuation range in the sequence corresponding to the photovoltaic unit start-up sequence is increased by adding the range of active power fluctuation range of photovoltaic unit with the order u1-1 in the sequence corresponding to the photovoltaic unit start-up sequence to obtain the range of active power fluctuation range of order u1 in the sequence corresponding to the photovoltaic unit start-up sequence. The upper limit of the range of order u1 is equal to the upper limit of the range of order u1-1 plus the upper limit of the active power fluctuation range of unit with the order u1 in the sequence corresponding to the photovoltaic unit start-up sequence. The lower limit of the range of order u1 is equal to the lower limit of the range of order u1-1 plus the lower limit of the active power fluctuation range of unit with the order u1 in the sequence corresponding to the photovoltaic unit start-up sequence.

[0240] (S4315) Jump to step S4313 until u1 equals the length of the photovoltaic unit start-up sequence and end step S4310.

[0241] For example, the active power of the photovoltaic power unit may fluctuate within the range of 310 to 360 MW in the future time T1. The photovoltaic unit start-up sequence is [Unit 1, Unit 3, Unit 2]. The active power of photovoltaic units 1, 2, and 3 may fluctuate within the ranges of 40 to 60, 50 to 70, and 40 to 80 respectively. Therefore, the active power fluctuation range sequence corresponding to the photovoltaic unit start-up sequence is [(350, 420), (390, 500), (440, 570)].

[0242] S4320) specifies a sequence of possible fluctuations in active power corresponding to the shutdown sequence of photovoltaic units, including:

[0243] S4321) Set variable u2, with an initial value of 1;

[0244] (S4322) Subtract the possible fluctuation range of active power of the photovoltaic power unit obtained in S4130 from the possible fluctuation range of active power of the photovoltaic unit ranked u2 in the photovoltaic shutdown sequence to obtain the range of ranked u2 in the sequence of possible fluctuation range of active power corresponding to the photovoltaic shutdown sequence. The upper limit of the range of ranked u2 is equal to the upper limit of the possible fluctuation range of active power of the photovoltaic power unit obtained in S4130 minus the upper limit of the possible fluctuation range of active power of the photovoltaic unit ranked u2 in the photovoltaic shutdown sequence. The lower limit of the range of ranked u2 is equal to the lower limit of the possible fluctuation range of active power of the photovoltaic power unit obtained in S4130 minus the lower limit of the possible fluctuation range of active power of the photovoltaic unit ranked u2 in the photovoltaic shutdown sequence.

[0245] S4323) Determine whether u2 is equal to the length of the photovoltaic shutdown sequence. If u2 is equal to the length of the photovoltaic shutdown sequence, terminate step S4320; otherwise, execute u2 = u2 + 1 and continue with the subsequent steps.

[0246] (S4324) Subtract the range of active power fluctuation of photovoltaic units ranked u2 in the sequence of possible fluctuation ranges of active power corresponding to the photovoltaic shutdown sequence from the range of ranked u2-1 in the sequence of possible fluctuation ranges of active power ...

[0247] (S4325) Jump to step S4323 until u2 equals the length of the photovoltaic shutdown sequence and end step S4320.

[0248] The S4400 calculation includes the actual active power generated by the photovoltaic power unit as a calculation factor, including:

[0249] S4410) The calculation quantity of the actual active power generated by the photovoltaic power unit is initially set to be equal to the actual active power generated by the unit;

[0250] S4420) accumulates the output dead zones of each unit of the photovoltaic power unit, which are given by the schedule or set manually, to obtain the unit output dead zone of the photovoltaic power unit;

[0251] S4430) Compares the actual active power generated by photovoltaic power units in calculations at fixed intervals with the actual active power generated by photovoltaic power units in the current period, including:

[0252] S4431) If the absolute value of the difference between the two is less than or equal to the output dead zone of the photovoltaic power unit, the actual active power generated by the photovoltaic power unit remains unchanged in the calculation.

[0253] (S4432) If the absolute value of the difference between the two is greater than the output dead zone of the photovoltaic power unit, then the actual active power generated by the photovoltaic power unit is included in the calculation and is equal to the actual active power generated by the photovoltaic power unit in the current period.

[0254] For example, if the dead zone of a photovoltaic power unit is 20MW, and the actual active power generated by the photovoltaic power unit is included in the calculation, the actual active power generated by the unit is 300MW. Due to power fluctuations, the actual active power generated by the unit changes to 305MW. Since the absolute value of the difference between the actual active power generated by the photovoltaic power unit (300MW) and the actual active power generated by the unit (305MW) is 5MW, which is less than the dead zone of 20MW, the actual active power generated by the photovoltaic power unit remains unchanged at 300MW. Later, due to further power fluctuations, the actual active power generated by the unit changes to 321MW. Thus, the absolute value of the difference between the actual active power generated by the photovoltaic power unit (300MW) and the actual active power generated by the unit (321MW) changes to 21MW, which is greater than the dead zone of 20MW. Therefore, the actual active power generated by the photovoltaic power unit changes to 321MW based on the actual active power generated by the unit.

[0255] The S4500 calculates the actual active power generated by the photovoltaic power unit, and the filtered values ​​are used in the calculation, including:

[0256] S4510) The filter value for the active power generated by the photovoltaic power unit is initially set to be equal to the active power generated by the unit.

[0257] S4520) Calculates the filtering threshold for the actual active power output of a photovoltaic power unit, including:

[0258] S4521) Set the scaling factor λ, where λ > 1;

[0259] S4522) The filtering threshold of the actual active power generated by the photovoltaic power unit is equal to the dead zone of the unit output described in S4420 multiplied by λ. In this embodiment, λ is assumed to be 3, then the filtering threshold is equal to 3 times the dead zone of the unit output.

[0260] S4530) Compares the filtered value of the actual active power generated by the photovoltaic power unit with the actual active power generated by the photovoltaic power unit in the current period at a fixed period, including:

[0261] S4531) If the absolute value of the difference between the two is less than or equal to the filtering threshold obtained in S4522, the actual active power generated by the photovoltaic power unit and the filtered value of the calculation remain unchanged.

[0262] (S4532) If the absolute value of the difference between the two is greater than the filtering threshold obtained in S4522, then the filtered value of the active power generated by the photovoltaic power unit is equal to the active power generated by the photovoltaic power unit in the current period.

[0263] S4600) calculates the unit primary frequency regulation target adjustment of the photovoltaic power unit, including:

[0264] S4610) Calculate the grid frequency deviation, which is equal to the grid rated frequency (50Hz) minus the grid real-time frequency.

[0265] S4620) If the absolute value of the grid frequency deviation is less than or equal to the primary frequency regulation threshold (dispatch given), then the unit primary frequency regulation target adjustment of the photovoltaic power unit is equal to 0.

[0266] (S4630) If the absolute value of the grid frequency deviation is greater than the primary frequency regulation threshold, the target adjustment amount of the primary frequency regulation of the photovoltaic power unit is equal to the actual active power generated by the photovoltaic power unit multiplied by the grid frequency deviation and then multiplied by the photovoltaic primary frequency regulation coefficient (given parameter by the grid).

[0267] The following is an example of the operation of the complementary integrated unit, specifically including:

[0268] By allocating the target active power values ​​for the hydropower unit and the energy storage unit, setting the primary frequency regulation coefficient for the hydropower unit, and calculating start-up and shutdown operation suggestions for the photovoltaic power unit, the control model aims to meet the total active power setpoint of the complementary integrated power supply, the primary frequency regulation requirements, and the charging and discharging requirements of the energy storage battery. Figure 1 As shown, to visually demonstrate the adjustment effect, the influence of primary frequency modulation is excluded in the control model. However, those skilled in the art will readily understand that even if primary frequency modulation is introduced, it will not affect the implementation effect of the method of this invention, including:

[0269] S100) Calculates the charge and discharge correction power of the energy storage power unit;

[0270] S110) Manually set the charging and discharging parameters α1 and the emergency charging and discharging parameters α2, where 0 < α1 < α2, and the units of α1 and α2 are both / h. In actual engineering, the energy storage unit battery is generally configured to support the rated power for charging or discharging for 30 minutes. Therefore, in this embodiment, α1 and α2 can be set to 0.6 / h and 1.2 / h, respectively, that is, the battery is charged and discharged at 30% and 60% of the rated power, respectively.

[0271] S120) Based on the overall battery state of the energy storage unit calculated by S3300, the charge / discharge coefficient α is calculated at fixed intervals, including:

[0272] S121) When the total battery capacity is in an ideal state, the charge / discharge coefficient α = 0;

[0273] S122) When the total battery charge is low, the charge / discharge coefficient α = α1;

[0274] S123) When the total battery charge is at an extremely low level, the charge / discharge coefficient α = α2;

[0275] S124) When the total battery charge is at a high level, the charge / discharge coefficient α = -α1;

[0276] S125) When the total battery charge is at an extremely high level, the charge / discharge coefficient α = -α2;

[0277] S126) When the total battery capacity is in a relatively ideal state, the charge-discharge coefficient remains unchanged. This step makes the relatively ideal state of the total battery capacity a buffer for changes in charge-discharge state, so as to prevent frequent changes in charge-discharge correction power. That is, the charge-discharge coefficient of the relatively ideal state of charge is determined by the total charge state of the battery before. When the total battery capacity changes from an extremely ideal state of charge to a relatively ideal state of charge, the charge-discharge coefficient α = 0. When the total battery capacity changes from a lower state of charge to a relatively ideal state of charge, the charge-discharge coefficient α = α1. When the total battery capacity changes from a higher state of charge to a relatively ideal state of charge, the charge-discharge coefficient α = -α1.

[0278] S130) Based on the charge / discharge coefficient obtained in S120, calculate the charge / discharge correction power of the energy storage power unit. The charge / discharge correction power is equal to...

[0279] (S200) The complementary integrated unit calculates the target value of the unit active power of the hydropower source. The target value of the unit active power of the hydropower source is equal to the total active power set value of the complementary integrated power source minus the filtered value of the actual active power of the photovoltaic power source obtained in S4500, plus the charge and discharge correction power obtained in S100. The step of using the actual active power of the photovoltaic power source as a filtered value in the calculation takes into account that the complementary integrated power source includes an energy storage power source, thus allowing for a suitable reduction in the sensitivity of the hydropower source to random fluctuations in the actual active power of the photovoltaic power source. For example, according to S4500, the sensitivity of the hydropower source to random fluctuations in the actual active power of the photovoltaic power source is one-third that of the energy storage power source.

[0280] The primary frequency scaling factor of the complementary integrated unit for the hydropower unit is calculated as (rated active power capacity of the photovoltaic power unit + rated active power capacity of the hydropower unit) ÷ rated active power capacity of the hydropower unit. Assuming the rated active power capacity of the hydropower unit is 200MW and the rated active power capacity of the photovoltaic power unit is 100MW, then the primary frequency scaling factor of the hydropower unit is (200+100) / 200=1.5.

[0281] The primary frequency regulation coefficient of a hydropower unit is equal to the primary frequency regulation coefficient of the hydropower unit issued by the power grid multiplied by the primary frequency scaling factor.

[0282] Comparing the target active power value of the hydropower unit with the unit joint operation area described in S2260, there are two possible results:

[0283] S211) When the target value of the active power of the unit is included in the joint operation area of ​​the unit, the target value of the active power of the unit is feasible, and therefore it is allocated to the hydraulic power unit.

[0284] The hydraulic power unit performs unit-level AGC allocation of the unit active power target value of the hydraulic power obtained in S2000 according to the S2000 method, and performs primary frequency regulation and secondary frequency regulation according to the active power of the hydraulic power unit. When each unit of the hydraulic power unit actually performs the primary frequency regulation task, it performs the primary frequency regulation regulation coefficient obtained in S200.

[0285] When each unit of the hydropower unit actually performs primary frequency regulation, it adjusts according to the primary frequency regulation coefficient obtained from S200. Assuming that when the grid frequency deviates to a certain extent, the primary frequency regulation of a certain unit of the hydropower unit was originally 40MW. In order to undertake the primary frequency regulation task of photovoltaic power, the primary frequency regulation of the unit is amplified to 40×1.5=60MW.

[0286] S212) When the target active power value of a unit is not included in the unit's joint operation area, and the target active power value of the unit is not feasible, subsequent steps are needed to find operational recommendations to make the target active power value of the unit feasible, including:

[0287] 1) Following the S2320 method, find operational recommendations that would make the target value of the unit active power of the hydraulic power source feasible by putting the units that are not in AGC control into AGC control, and prioritize the operational recommendations.

[0288] 2) Following the S2330 method, find operational recommendations that make the target active power of the hydropower unit feasible by converting non-generating units into generating units and putting them into AGC mode, and prioritize the operational recommendations.

[0289] 3) Following the S2340 method, find operational recommendations that make the target active power of the hydropower unit feasible by switching the generating unit to a non-generating state, and prioritize the operational recommendations.

[0290] S300 generates start-up and shutdown operation suggestions for photovoltaic units:

[0291] S310) Calculate the active power capacity range of the photovoltaic power unit within the future time period T1, where T1 is the artificially set parameter described in S4100:

[0292] S311) Calculate the lower limit of the active power capacity of the photovoltaic power unit at each time point in the future time period T1, or the lower limit of each continuous interval of the capacity, including:

[0293] If the dispatcher issues the active power plan curve of the complementary integrated power source in advance, then the total active power set value of the complementary integrated power source at each time point in the future T1 time period will be subtracted from the upper limit of the joint operation area of ​​the hydropower unit obtained by S2260 (if the joint operation area only includes one continuous section) or the upper limit of each continuous section of the joint operation area (if the joint operation area includes multiple continuous sections). This will be the lower limit of the unit active power capacity of the photovoltaic power source at each time point in the future T1 time period (if the joint operation area only includes one continuous section) or the lower limit of the capacity of each continuous section of the photovoltaic power source (if the joint operation area includes multiple continuous sections).

[0294] If the dispatcher does not issue the active power plan curve of the complementary integrated power source in advance, then the upper limit of the joint operation area of ​​the hydropower unit obtained by S2260 (when the joint operation area only includes one continuous section) or the upper limit of each continuous section of the joint operation area (when the joint operation area includes multiple continuous sections) will be subtracted from the current total active power setpoint of the complementary integrated power source. This will be the lower limit of the active power capacity of the photovoltaic power unit at each time point in the future (when the joint operation area only includes one continuous section) or the lower limit of the capacity of each continuous section (when the joint operation area includes multiple continuous sections).

[0295] S312) Calculate the upper limit of the active power capacity of the photovoltaic power unit at each time point in the future time period T1, or the upper limit of each continuous interval of the capacity, including:

[0296] If the dispatcher issues the active power plan curve of the complementary integrated power source in advance, then the total active power set value of the complementary integrated power source at each time point in the future T1 time period will be subtracted from the lower limit of the joint operation area of ​​the hydropower unit obtained by S2260 (if the joint operation area only includes one continuous section) or the lower limit of each continuous section of the joint operation area (if the joint operation area includes multiple continuous sections). This will be the upper limit of the active power capacity of the photovoltaic power unit at each time point in the future T1 time period or the upper limit of each continuous section of the capacity.

[0297] If the dispatcher does not issue the active power plan curve of the complementary integrated power source in advance, then the total active power set value of the current complementary integrated power source is subtracted from the lower limit of the joint operation area of ​​the hydropower unit obtained by S2260 (if the joint operation area only includes one continuous section) or the lower limit of each continuous section of the joint operation area (if the joint operation area includes multiple continuous sections). This is the upper limit of the active power capacity of the photovoltaic power unit at each time point in the future T1 time period or the upper limit of each continuous section of the capacity.

[0298] (S313) The active power capacity range of the photovoltaic power unit within the future time period T1 is the intersection of the active power capacity ranges of the photovoltaic power unit at each time point within the future time period T1. This range may be a continuous interval or composed of multiple continuous intervals. Assuming that the total active power setpoint gradually decreases from 900MW to 800MW and then gradually increases to 1000MW within the future time period T1, with the total active power setpoints at several time points being 900, 850, 800, 950, and 1000MW respectively, the joint operation zone of the hydropower unit is (300, 60...). If 0)∪(700,950), then the active power capacity range of the photovoltaic power unit at each time point in the future time T1 is (-50,200)∪(300,600), (-100,150)∪(250,550), (-150,100)∪(200,500), (0,250)∪(350,650), and (50,300)∪(400,700). Taking the intersection of the above ranges, we can obtain the active power capacity range of the photovoltaic power unit in the future time T1 as (50,100)∪(400,500).

[0299] S320) Calculate the quantified value of the mismatch between the current photovoltaic power unit's on / off status and the setpoint of the total active power of the complementary integrated power supply within the future time T1:

[0300] S321) Calculate the mismatch degree between the continuous intervals (one or more continuous intervals constituting the range) of the active power capacity of the photovoltaic power unit in the future time T1 obtained in S310 and the upper limit of the possible fluctuation range of the active power of the photovoltaic power unit in the future time T1. Subtract the upper limit of each continuous interval of the active power capacity of the photovoltaic power unit in the future time T1 from the upper limit of the possible fluctuation range of the active power of the photovoltaic power unit in the future time T1, and judge the calculation results respectively. If it is greater than 0, the upper limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the upper limit mismatch degree is equal to 0.

[0301] S322) Calculate the mismatch degree between the continuous intervals included in the active power capacity range of the photovoltaic power unit in the future time T1 obtained in S310 and the lower limit of the possible fluctuation range of the active power of the photovoltaic power unit in the future time T1. Subtract the lower limit of the possible fluctuation range of the active power of the photovoltaic power unit in the future time T1 from the lower limit of the continuous intervals included in the active power capacity range of the photovoltaic power unit in the future time T1, and judge the calculation results respectively. If it is greater than 0, the lower limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the lower limit mismatch degree is equal to 0.

[0302] S323) According to the one-to-one correspondence between the continuous intervals included in the active power capacity range of the new power unit within the future time T1 obtained from S313, the upper limit mismatch degree of each continuous interval obtained from S321 is subtracted from the lower limit mismatch degree of each continuous interval obtained from S322. The absolute value of all results is taken, and then the smallest value is taken from the absolute values ​​of all results to obtain the quantified value of the mismatch between the current photovoltaic power unit's start-up and shutdown status and the set value of the total active power of the complementary integrated power supply within the future time T1. For example, if the active power capacity range of the photovoltaic power unit within the future time T1 is (200, 250), then when the active power of the photovoltaic power unit may fluctuate within the range of (100, 130), the mismatch degree of the upper limit of the range is max[0, 130-250] = 0, and the mismatch degree of the lower limit of the range is max[0, 200-100] = 100. Therefore, the quantified value of the mismatch is |0-100| = 100, where max[] is the function for finding the maximum value.

[0303] S330) Seek operational recommendations for shutting down photovoltaic (PV) generating units, specifically including:

[0304] S3310) Manually set the threshold parameter for suggesting a shutdown operation;

[0305] S3320) Set variable v3, and initialize v3 to 1;

[0306] S3330) If v3 is less than or equal to the length of the photovoltaic shutdown sequence, then set the original mismatch metric variable, which is equal to the mismatch metric obtained in S320; otherwise, proceed to step S3360.

[0307] S3340) Calculate the quantified value of the mismatch between the range of sorted v3 in the sequence of possible fluctuations in active power corresponding to the photovoltaic shutdown sequence and the setpoint of the total active power of the complementary integrated power source within the future time T1, including:

[0308] S3341) Calculate the upper limit mismatch degree between the continuous intervals included in the active power capacity range of the photovoltaic power unit in the future time T1 obtained in S310 and the range of sorted v3 in the active power possible fluctuation range sequence corresponding to the photovoltaic shutdown sequence. Subtract the upper limit of each continuous interval included in the active power capacity range of the photovoltaic power unit in the future time T1 from the upper limit of the range of sorted v3 in the active power possible fluctuation range sequence corresponding to the photovoltaic shutdown sequence, and judge the calculation results respectively. If it is greater than 0, the upper limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the upper limit mismatch degree is equal to 0.

[0309] S3342) Calculate the mismatch degree between the lower limit of the range of sorted v3 in the sequence of possible fluctuations of active power in the photovoltaic power supply unit within the future time T1 and the continuous intervals included in the unit active power capacity range of the photovoltaic power supply unit. Subtract the lower limit of the range of sorted v3 in the sequence of possible fluctuations of active power in the photovoltaic shutdown sequence from the lower limit of the continuous intervals included in the unit active power capacity range of the photovoltaic power supply unit within the future time T1. Judge the calculation results respectively. If it is greater than 0, the lower limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the lower limit mismatch degree is equal to 0.

[0310] S3343) According to the one-to-one correspondence between the active power capacity range of the new power unit within the future time T1 obtained from S313 and each continuous interval, the upper limit mismatch degree of each continuous interval obtained from S3341 is subtracted from the lower limit mismatch degree of each continuous interval obtained from S3342. The absolute value of all results is taken, and then the smallest value is taken from the absolute values ​​of all results to obtain the quantified value of the mismatch between the range of v3 in the active power possible fluctuation range sequence corresponding to the photovoltaic shutdown sequence and the set value of the total active power of the complementary integrated power supply within the future time T1.

[0311] S3350) Subtract the mismatch measurement value obtained from S3343 from the original mismatch measurement value variable, and perform the following operations based on the calculation result, including:

[0312] S3351) If the calculation result is greater than or equal to the judgment threshold parameter set in S3310, then v3 = v3 + 1. If v3 is greater than the length of the photovoltaic shutdown sequence at this time, then jump to step S3360. Otherwise, update the original mismatch metric variable to the mismatch metric obtained in S3343, and jump to step S3340 to continue execution.

[0313] S3352) If the calculation result is less than the judgment threshold parameter set in S3310, then proceed to step S3360 to continue execution.

[0314] S3360) Generates operation suggestions based on the value of variable v3, including:

[0315] S3361) If v3 = 1, no operation suggestions are generated;

[0316] S3362) If v3 > 1, then generate a shutdown operation suggestion, suggesting that the photovoltaic units corresponding to sequence 1 to v3-1 in the photovoltaic shutdown sequence be shut down.

[0317] S340) Seek operational recommendations for starting up available but not yet generating photovoltaic (PV) units, including:

[0318] S3410) Manually set the threshold parameters for suggesting power-on operations;

[0319] S3420) Set variable v4, and initialize v4 to 1;

[0320] S3430) If v4 is less than or equal to the photovoltaic unit start-up sequence length, then set the original mismatch metric variable, and the original mismatch metric variable is equal to the mismatch metric obtained in S320; otherwise, jump to step S3460.

[0321] S3440) Calculate the quantified value of the mismatch between the range of sorted v4 in the sequence corresponding to the active power fluctuation range of the photovoltaic unit start-up sequence and the setpoint of the total active power of the complementary integrated power supply within the future time T1, including:

[0322] S3441) Calculate the mismatch degree between the upper limit of the range of the active power capacity of the photovoltaic power unit within the future time T1 obtained in S310 and the range of sorted v4 in the sequence of possible fluctuation range of active power corresponding to the photovoltaic unit start-up sequence. Subtract the upper limit of each continuous interval included in the range of the active power capacity of the photovoltaic power unit within the future time T1 from the upper limit of the range of sorted v4 in the sequence of possible fluctuation range of active power corresponding to the photovoltaic unit start-up sequence, and judge the calculation results respectively. If it is greater than 0, the upper limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the upper limit mismatch degree is equal to 0.

[0323] S3442) Calculate the mismatch degree between the lower limit of the range of the active power capacity of the photovoltaic power unit within the future time T1 obtained in S310 and the range of sorted v4 in the active power fluctuation range sequence corresponding to the photovoltaic unit start-up sequence. Subtract the lower limit of the range of sorted v4 in the active power fluctuation range sequence corresponding to the photovoltaic unit start-up sequence from the lower limit of the range of the active power capacity of the photovoltaic power unit within the future time T1. Judge the calculation results. If it is greater than 0, the lower limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the lower limit mismatch degree is equal to 0.

[0324] S3443) According to the one-to-one correspondence between the active power capacity range of the new power unit in the future time T1 obtained from S313 and each continuous interval, the upper limit mismatch degree of each continuous interval obtained from S3441 is subtracted from the lower limit mismatch degree of each continuous interval obtained from S3442. The absolute value of all results is taken, and then the smallest value is taken from the absolute values ​​of all results to obtain the quantified value of the mismatch between the range of v4 in the active power possible fluctuation range sequence corresponding to the photovoltaic unit start-up sequence and the set value of the total active power of the complementary integrated power supply in the future time T1.

[0325] S3450) Subtract the mismatched metric value obtained from S3443 from the original mismatched metric value variable, and perform the following operations based on the calculation result, including:

[0326] S3451) If the calculation result is greater than or equal to the judgment threshold parameter set in S3410, then v4 = v4 + 1. If v4 is greater than the photovoltaic unit start-up sequence length at this time, then jump to step S3460. Otherwise, update the original mismatch quantification value variable to the mismatch quantification value obtained in S3443, and jump to step S3440 to continue execution.

[0327] S3452) If the calculation result is less than the judgment threshold parameter set in S3410, then proceed to step S3460 to continue execution.

[0328] S3460) Generate operation suggestions based on the value of variable v4, including:

[0329] S3461) If v4 = 1, no operation suggestions are generated;

[0330] S3462) If v4 > 1, then generate a startup operation suggestion, suggesting that the startup operation be performed on the photovoltaic units corresponding to sequence 1 to v4-1 in the photovoltaic unit startup sequence.

[0331] Then, the shutdown operation suggestions for photovoltaic units generated by S330 are displayed in an orderly manner.

[0332] The startup operation suggestions for photovoltaic units generated by S340 are displayed in an orderly manner.

[0333] The complementary integration unit sends the suggested shutdown and startup operations for the photovoltaic (PV) units to the PV power supply unit; the PV power supply unit then distributes these suggestions to each PV generator unit for execution.

[0334] S400) calculates the target value of the active power of the energy storage power unit, including:

[0335] S410) Add the set value of the total active power of the complementary integrated power supply to the unit primary frequency regulation correction of the hydropower unit, then subtract the unit active power actual value of the photovoltaic power unit for calculation, and then subtract the unit active power actual value of the hydropower unit to obtain the total active power regulation deviation of the hydropower unit and the photovoltaic power unit.

[0336] S420) The initial compensation adjustment amount of the energy storage power unit is set to the total active power adjustment deviation obtained in S410, and then the compensation adjustment amount of the energy storage power unit is compared with the current total active power adjustment deviation at a fixed period:

[0337] S421) When the absolute value of the difference between the two is greater than the dead zone of the active power regulation of the energy storage power unit, the single compensation regulation of the energy storage power unit is equal to the total active power regulation deviation of the current hydropower unit and photovoltaic power unit.

[0338] S422) When the absolute value of the difference between the two is less than or equal to the dead zone of the active power regulation of the energy storage power unit, the compensation regulation amount of the energy storage power unit remains unchanged.

[0339] S430) Referencing the S430 method, dead-zone processing is applied to the compensation adjustment of the energy storage power unit to obtain the target value of the unit's active power. The processing logic is as follows: Figure 5 As shown, it includes:

[0340] S431) Manually set the timer and time parameter T4;

[0341] S432) When the absolute value of the total active power regulation deviation obtained from S410 is less than or equal to the active power regulation dead zone of the hydraulic power unit, the timer set in S431 starts counting.

[0342] S433) When the absolute value of the total active power regulation deviation obtained from S410 is greater than the active power regulation dead zone of the hydraulic power unit, the timer set in S431 is reset to zero.

[0343] S434) When the timer time is less than the time parameter T4, the active power target value of the energy storage power unit is equal to the compensation adjustment amount obtained in S420.

[0344] (S435) When the timer time is greater than or equal to the time parameter T4, the active power target value of the energy storage power unit is equal to 0.

[0345] The complementary integrated unit distributes the target active power value of the unit obtained in S430 to the energy storage power unit. The energy storage power unit performs unit-level AGC allocation according to the method in S3000 and adjusts the active power of each energy storage unit.

[0346] Figure 1 The regulation effect of the complementary integrated power supply in the control model shown is as follows: Figure 6 As shown, it is easy to see that: 1) Thanks to the compensation effect of the hydropower source for the large deviation of the actual active power of the photovoltaic power unit, and the compensation effect of the energy storage source for the random fluctuation of the actual active power of the photovoltaic power unit, the total active power of the complementary integrated power source has always maintained extremely high stability. In addition, except for a few time periods, the energy storage source is basically in a low load state, which ensures the battery's "shallow charging and shallow discharging" requirements.

[0347] 2) Thanks to the superior regulation performance of the energy storage power supply, when the total active power setpoint of the complementary integrated power supply changes from 300MW to 400MW in 70s, the actual value of the total active power generated by the complementary integrated power supply responds very well, and the regulation delay, regulation rate, regulation accuracy and other indicators are all at a high level.

[0348] 3) When the charge and discharge correction power of the energy storage power battery changes from 0 to 100M in 140s, the actual active power of the hydropower unit increases accordingly, thereby enabling the energy storage power battery to enter the charging state. This process does not adversely affect the stability of the total active power of the complementary integrated power supply.

[0349] To further demonstrate the "shallow charge and shallow discharge" characteristics of the energy storage battery in the method of this invention, a simulation model of hydropower + energy storage + photovoltaic is constructed. This model includes three energy storage units with a battery capacity ratio of 5:8:10 within the energy storage unit. The control model is as follows: Figure 7 As shown, the relationships between the total active power output of the integrated power supply, the active power output of the hydropower unit, the active power output of the photovoltaic unit, the active power output of each unit in the energy storage power supply unit, the battery state of charge of each unit in the energy storage power supply unit, the battery capacity ratio of each unit in the energy storage power supply unit, the total battery capacity ratio of the energy storage power supply unit, and the charge / discharge correction power of the energy storage power supply unit are respectively shown in the following diagrams. Figure 8 As shown, from Figure 8 The adjustment effect can be seen in:

[0350] 1) The adjustment range of the active power regulation of the energy storage unit is related to the battery capacity and the battery state of charge. Although the battery capacity of energy storage unit 3 is twice that of energy storage unit 1, the initial charge capacity ratio of the battery of energy storage unit 3 is much lower than that of energy storage unit 1, which results in the discharge range of energy storage unit 3 being smaller than that of energy storage unit 1.

[0351] 2) Although the battery charge capacity ratios of the three energy storage units were artificially set to be significantly different in the initial stage of the simulation, under the control of the "shallow charge and shallow discharge" strategy of this invention, the battery charge capacity ratios of all energy storage units gradually tend to be consistent. At the same time, as mentioned above, since the charging and discharging strategy of this invention can maintain a good balance of the total charge capacity of the energy storage unit cells, the batteries of all energy storage units are naturally in a relatively balanced state (neither overcharged nor over-discharged).

[0352] The embodiments given above are preferred examples for implementing the present invention, and the present invention is not limited to the above embodiments. Any non-essential additions or substitutions made by those skilled in the art based on the technical features of the present invention are within the protection scope of the present invention.

Claims

1. A method for active power regulation of an integrated power source that complements hydropower, photovoltaic, and energy storage, characterized in that, The complementary integrated power control center coordinates and controls the hydropower, energy storage and photovoltaic power. The complementary integrated power control center is equipped with a complementary integration unit, a hydropower unit, an energy storage unit and a photovoltaic power unit. The hydropower unit obtains intermediate control parameters for the hydropower source based on the basic parameters of the hydropower source and sends them to the complementary integration unit; the energy storage unit obtains intermediate control parameters for the energy storage source, including battery status and energy storage regulation coefficient, based on the basic parameters of the energy storage source and sends them to the complementary integration unit; the photovoltaic power unit sends intermediate control parameters for the photovoltaic source to the complementary integration unit. The complementary integration unit performs the following adjustments based on the acquired parameters: S100) Calculate the charge / discharge correction power of the energy storage power unit: Where α is the charge-discharge coefficient, which is updated at fixed intervals based on the overall battery charge status of the energy storage power unit. and These are the maximum and minimum battery charge values ​​for energy storage unit i, respectively. S200) Calculate the target value of the unit active power of the hydropower source. The target value of the unit active power of the hydropower source is equal to the total active power set value of the complementary integrated power source minus the filter value of the actual active power of the photovoltaic power source unit, plus the charge and discharge correction power of the energy storage power source unit. The filter value of the actual active power of the photovoltaic power source unit is updated at a fixed period based on the actual active power of the photovoltaic power source unit, the filter threshold, and the output dead zone of the photovoltaic power source unit. Calculate the primary frequency regulation coefficient of the hydropower unit. The primary frequency regulation coefficient of the hydropower unit is the primary frequency regulation coefficient of the hydropower unit issued by the grid multiplied by the primary frequency regulation scaling factor. The primary frequency regulation scaling factor is equal to (rated active power capacity of the photovoltaic power unit + rated active power capacity of the hydropower unit) ÷ rated active power capacity of the hydropower unit. Each unit of the hydropower unit performs the primary frequency regulation task according to the primary frequency regulation coefficient. S300 generates start-up and shutdown recommendations for photovoltaic units: After determining the target value of the active power of the hydropower unit, obtain the quantitative value of the mismatch between the current start-up and shutdown status of the photovoltaic power unit and the set value of the total active power of the complementary integrated power in the future time T1. Then, the quantified value of the mismatch between the current photovoltaic power unit's start-up and shutdown status and the set value of the total active power of the complementary integrated power supply within the future time T1 is compared with the quantified value of the mismatch between the sequence of possible fluctuations in active power corresponding to the photovoltaic unit's start-up and shutdown sequence and the set value of the total active power of the complementary integrated power supply within the future time T1. Based on the comparison results, operation suggestions are generated, and the generated photovoltaic unit start-up and shutdown operation suggestions are displayed in an orderly manner. S400) Calculate the target active power value of the energy storage power unit: The energy storage power unit performs unit-level AGC allocation based on the target value of the unit's active power obtained after dead-zone processing, and adjusts the active power of each energy storage unit.

2. The active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage power sources as described in claim 1, characterized in that, The parameters acquired by the complementary integration unit include: Parameters input to the complementary integrated unit (S1100): S1111) The total active power setting value of the complementary integrated power supply directly input; S1112) Rated active power capacity of unit, where the rated active power capacity of unit of hydropower and photovoltaic power is equal to the sum of the rated active power capacity of the single unit of the power generation unit of this type of power unit, and the rated active power capacity of unit of energy storage power depends on the rated capacity of each energy storage unit and the state of charge of the battery. The actual active power generated by unit S1113) is equal to the sum of the actual active power generated by each unit of the hydropower, energy storage, and photovoltaic power units. S1114) The active power regulation dead zone of the unit is equal to the sum of the active power regulation dead zones of the single unit of the hydropower and energy storage power units that are currently in operation; Input parameters sent by the S1120 hydraulic power unit: S1121) The unit primary frequency regulation target adjustment of the hydropower unit is equal to the sum of the single unit primary frequency regulation target adjustment of the generating units; S1122) Unit joint operation zone of hydraulic power unit; S1123) Actual frequency regulation of the primary frequency regulation of the hydraulic power unit; S1124) The unit primary frequency regulation correction amount of the hydraulic power unit is equal to the actual adjustment amount of the unit primary frequency regulation of the hydraulic power unit when the actual adjustment amount of the primary frequency regulation of each unit of the hydraulic power unit can be measured; otherwise, it is equal to the unit primary frequency regulation target adjustment amount of the hydraulic power unit as described in S1121. S1130) Parameters sent by the energy storage power unit: the charge and discharge correction power of the energy storage power unit; Input parameters sent by the photovoltaic power unit (S1140): S1141) The actual active power generated by the photovoltaic power unit is included in the calculation. The photovoltaic power unit updates the actual active power generated by the unit and the dead zone of each photovoltaic unit at a fixed period. S1142) The actual active power generated by the photovoltaic power unit is used as a filter value in the calculation. The photovoltaic power unit updates the actual active power generated by the unit, the scaling factor and the dead zone of each photovoltaic unit at a fixed period. S1143) The possible fluctuation range of active power of photovoltaic power unit is a prediction result of the fluctuation range of active power of photovoltaic power unit within a certain period of time in the future. S1144) The start-up sequence and shutdown sequence of the photovoltaic power unit, and the corresponding active power fluctuation range sequence respectively; (S1145) The unit primary frequency regulation target adjustment of a photovoltaic power unit is equal to the sum of the unit primary frequency regulation target adjustment of a photovoltaic unit that is generating electricity.

3. The active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage as described in claim 1, characterized in that, The calculation of the charge / discharge correction power of the energy storage power unit includes the following operations: S110) Set the charging / discharging parameter α1 and the emergency charging / discharging parameter α2, where 0 < α1 < α2; S120) Based on the overall battery charge state of the energy storage power unit, the charge-discharge coefficient α is calculated at fixed intervals: S121) When the total battery charge is in an ideal state, the charge-discharge coefficient α = 0; S122) When the total battery charge is at a low level, the charge / discharge coefficient α = α1; S123) When the total battery charge is at an extremely low level, the charge / discharge coefficient α = α2; S124) When the total battery charge is at a high level, the charge / discharge coefficient α = -α1; S125) When the total battery charge is at an extremely high level, the charge / discharge coefficient α = -α2; S126) When the total battery charge is in a relatively ideal state, the charge-discharge coefficient remains unchanged. S130) Calculate the charge and discharge correction power of the energy storage power unit based on the charge and discharge coefficient; Charge / discharge correction power is ; The overall state of charge of the battery in the energy storage power unit is determined as follows: (S1310) When 0≤r<R1', the battery of the energy storage power unit is in an extremely low charge state. (S1320) When R1'≤r<R2', the battery of the energy storage power unit is generally in a low charge state; (S1330) When R2'≤r<R3' or R4'<r≤R5', the battery of the energy storage power unit is in a relatively ideal state of charge. (S1340) When R3'≤r≤R4', the battery of the energy storage power unit is in an ideal state of charge. (S1350) When R5'<r≤R6', the battery of the energy storage power unit is generally in a high charge state; (S1360) When R6'<r≤1, the battery of the energy storage power unit is in an extremely high charge state. Where r is the proportion of the total battery capacity of the energy storage power unit. In the formula, SOC i The state of charge of the battery in energy storage unit i; R1'~R6' are the judgment thresholds, where 0 < R1' < R2' < R3' < R4' < R5' < R6' < 1, R1' + R6' = 1, R2' + R5' = 1, and R3' + R4' = 1.

4. The active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage as described in claim 1, characterized in that, In calculating the target value of the unit active power of the hydropower source, the actual active power generated by the photovoltaic power source unit is included in the calculation as a filtered value: The filter value for the active power generated by the photovoltaic power unit is initially set to be equal to the active power generated by the photovoltaic power unit. The filtered value of the actual active power generated by the photovoltaic power unit is compared with the actual active power generated by the photovoltaic power unit in the current period according to a fixed period: If the absolute value of the difference between the two is less than or equal to the filtering threshold, the filtered value of the active power generated by the photovoltaic power unit remains unchanged in the calculation; if the absolute value of the difference between the two is greater than the filtering threshold, the filtered value of the active power generated by the photovoltaic power unit in the calculation is equal to the active power generated by the photovoltaic power unit in the current period. The filtering threshold is equal to the dead zone of the photovoltaic unit output multiplied by the scaling factor λ, where λ > 1.

5. The active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage as described in claim 1, characterized in that, To find operational recommendations that make the target active power value of the unit feasible, specifically including the following actions: S2320) Seeking operational recommendations to make the target active power value of the hydropower unit feasible by putting units in the hydropower unit that are not currently under AGC control into AGC control, including: S2321) Set the loop variable i1, and set the initial value of i1 to 1; S2322) Determine i1. If i1 is greater than the number of units not in AGC, terminate S2320. Otherwise, continue to execute the following steps to find an operational suggestion to put i1 units not in AGC into AGC control so that the unit active power target value of the hydraulic power source becomes feasible. S2323) List all possible combinations of selecting i1 units from all units that have not been put into AGC, for a total of C(j1,i1) combinations, where C() is the combination number function and j1 is the number of units that have not been put into AGC. S2324) According to the C(j1,i1) combination methods listed in S2323, the units that have not been put into AGC are assumed to be put into AGC in each method, and the unit joint operation area and the unit joint recommended operation area are recalculated using the S2200 method. Then, based on the newly calculated unit joint operation area, the feasibility of the unit active power target value is re-evaluated using the S2300 method. (S2325) Based on the calculation results of S2324, if there is one and only one way to regenerate the unit joint operation area that makes the unit active power target value feasible, then an operation suggestion is generated; if there are multiple ways to regenerate the unit joint operation area that make the unit active power target value feasible, then operation suggestions are generated according to these methods respectively, and the process jumps to step S2326 to continue execution; if there is no way to regenerate the unit joint operation area that makes the unit active power target value feasible, then i1 = i1 + 1, and then the process jumps to step S2322 to determine whether i1 is greater than the number of units that have not put AGC into operation, and decides whether to execute the subsequent steps based on the determination result. S2326) Prioritize the multiple operation suggestions generated in S2325. The priority is based on the changed unit joint operation area and unit joint suggestion operation area corresponding to these operation suggestions. The priority is based on the following criteria from highest to lowest importance: whether the unit active power target value belongs to the unit joint suggestion operation area, and the absolute value of the difference between the unit active power target value and the boundary or segment boundary of the unit joint operation area. S2330) Seeking operational recommendations to make the target active power value of the hydropower unit feasible by converting non-generating units in the hydropower unit to generating mode and engaging AGC, including: S2331) Set the loop variable i2, and set the initial value of i2 to 1; S2332) Determine i2. If i2 is greater than the number of available but not generating units, terminate S2330. Otherwise, continue to execute the following steps to find an operational suggestion to convert i2 available but not generating units into generating state and put them into AGC so that the unit active power target value of the hydropower source becomes feasible. S2333) List all possible combinations of selecting i2 units from all available but not generating units, totaling C(j2,i2) combinations, where j2 is the number of available but not generating units; S2334) According to the C(j2,i2) combination methods listed in S2333, the available but non-generating units selected by each method are assumed to be generating units and put into AGC. The unit joint operation area and the unit joint recommended operation area are recalculated using the S2200 method. Then, based on the newly calculated unit joint operation area, the feasibility of the unit active power target value is reassessed using the S2300 method. (S2335) Based on the calculation results of S2334, if there is one and only one way to regenerate the unit joint operation area that makes the unit active power target value feasible, then an operation suggestion is generated; if there are multiple ways to regenerate the unit joint operation area that make the unit active power target value feasible, then operation suggestions are generated according to these methods respectively: "Convert the available but non-generating units selected by the corresponding method to generating state and put them into AGC", and then jump to step S2336 to continue execution; if there is no way to regenerate the unit joint operation area that makes the unit active power target value feasible, then i2 = i2 + 1, and then jump to step S2332 to judge whether i2 is greater than the number of available but non-generating units, and decide whether to execute the subsequent steps based on the judgment result; S2336) Prioritize the multiple operation suggestions generated in S2335. The ranking is based on the changed unit joint operation area and unit joint suggestion operation area corresponding to these operation suggestions. The ranking criteria are as follows, from highest to lowest importance: whether the unit active power target value belongs to the unit joint suggestion operation area, and the absolute value of the difference between the unit active power target value and the boundary or segment boundary of the unit joint operation area. S2340) Seeking operational recommendations to make the target active power value of the hydropower unit feasible by switching the generating units in the hydropower unit to a non-generating state, including: S2341) Set the loop variable i3, and set the initial value of i3 to 1; S2342) Determine i3. If i3 is greater than the number of generating units, terminate S2340. Otherwise, continue to execute the following steps to find an operational suggestion to convert i3 generating units to non-generating state so that the unit active power target value of the hydropower source becomes feasible. S2343) List all possible combinations of selecting i3 generators from all generating units, totaling C(j3,i3) combinations, where j3 is the number of generating units; S2344) According to the C(j3,i3) combination methods listed in S2343, the generating units selected in each method are assumed to be in a non-generating state, and the unit joint operation area and unit joint recommended operation area are recalculated using the S2200 method. Then, based on the newly calculated unit joint operation area, the feasibility of the unit active power target value is reassessed using the S2300 method. (S2345) Based on the calculation results of S2344, if there is one and only one way to regenerate the unit joint operation area that makes the unit active power target value feasible, then an operation suggestion is generated; if there are multiple ways to regenerate the unit joint operation area that make the unit active power target value feasible, then operation suggestions are generated according to these methods respectively: "switch the generating units selected by the corresponding method to non-generating state", and the process jumps to step S2346 to continue execution; if there is no way to regenerate the unit joint operation area that makes the unit active power target value feasible, then i3 = i3 + 1, and then the process jumps to step S2342 to determine whether i3 is greater than the number of generating units, and decides whether to execute the subsequent steps based on the determination result. S2346) Prioritize the multiple operation suggestions generated in S2345. The priority is based on the combination of i3 generating units selected from the generating units corresponding to these operation suggestions, and the changed unit joint operation area and unit joint suggested operation area range corresponding to each operation suggestion obtained in S2344. The priority criteria are as follows, from highest to lowest importance: the number of generating units that have not put AGC into operation and the number of generating units that have put AGC into operation, whether the unit active power target value belongs to the unit joint suggested operation area, and the absolute value of the difference between the unit active power target value and the boundary or segment boundary of the unit joint operation area. S2350) categorizes the operation suggestions generated by S2320, S2330, and S2340, and displays them in order of priority.

6. The active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage as described in claim 1, characterized in that, The recommended procedures for starting and stopping photovoltaic power units include the following: S310) Calculate the active power capacity range of the photovoltaic power unit within the future time period T1, where T1 is a manually set time parameter: S311) Calculate the lower limit of the active power capacity of the photovoltaic power unit at each time point in the future time period T1, or the lower limit of each continuous interval of the capacity, including: If the dispatcher issues the active power plan curve of the complementary integrated power source in advance, the total active power set value of the complementary integrated power source at each time point in the future T1 time period will be subtracted from the upper limit of the joint operation area of ​​the hydropower unit or the upper limit of each continuous interval of the joint operation area to obtain the lower limit of the unit active power capacity of the photovoltaic power unit at each time point in the future T1 time period or the lower limit of each continuous interval of the capacity. If the dispatcher does not issue the active power plan curve of the complementary integrated power source in advance, the upper limit of the joint operation area of ​​the hydropower unit or the upper limit of each continuous interval of the joint operation area will be subtracted from the current total active power set value of the complementary integrated power source to obtain the lower limit of the active power capacity of the photovoltaic power unit at each time point in the future T1 time period or the lower limit of each continuous interval of the capacity. S312) Calculate the upper limit of the active power capacity of the photovoltaic power unit at each time point in the future time period T1, or the upper limit of each continuous interval of the capacity, including: If the dispatcher issues the active power plan curve of the complementary integrated power source in advance, the total active power set value of the complementary integrated power source at each time point in the future T1 time period will be subtracted from the lower limit of the joint operation area of ​​the hydropower unit or the lower limit of each continuous interval of the joint operation area to obtain the upper limit of the unit active power capacity of the photovoltaic power unit at each time point in the future T1 time period or the upper limit of each continuous interval of the capacity. If the dispatcher does not issue the active power plan curve of the complementary integrated power source in advance, the lower limit of the joint operation area of ​​the hydropower unit or the lower limit of each continuous interval of the joint operation area will be subtracted from the current total active power set value of the complementary integrated power source to obtain the upper limit of the active power capacity of the photovoltaic power unit at each time point in the future T1 time period or the upper limit of each continuous interval of the capacity. S313) The active power capacity of a photovoltaic power unit within the future time period T1 is the intersection of the active power capacity of the photovoltaic power units at each time point within the future time period T1. S320) Calculate the quantified value of the mismatch between the current photovoltaic power unit's on / off status and the setpoint of the total active power of the complementary integrated power supply within the future time T1: S321) Calculate the mismatch degree between each continuous interval included in the active power capacity range of the photovoltaic power unit in the future time T1 and the upper limit of the possible fluctuation range of the active power of the photovoltaic power unit in the future time T1. Subtract the upper limit of each continuous interval included in the active power capacity range of the photovoltaic power unit in the future time T1 from the upper limit of the possible fluctuation range of the active power of the photovoltaic power unit in the future time T1, and judge the calculation results respectively. If it is greater than 0, the upper limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the upper limit mismatch degree is equal to 0. S322) Calculate the mismatch degree between each continuous interval included in the active power capacity range of the photovoltaic power unit in the future time T1 and the lower limit of the possible fluctuation range of the active power of the photovoltaic power unit in the future time T1. Subtract the lower limit of the possible fluctuation range of the active power of the photovoltaic power unit in the future time T1 from the lower limit of each continuous interval included in the active power capacity range of the photovoltaic power unit in the future time T1, and judge the calculation results respectively. If it is greater than 0, the lower limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the lower limit mismatch degree is equal to 0. S323) According to the one-to-one correspondence between the active power capacity range of the photovoltaic power unit in the future time T1 obtained from S313 and each continuous interval, the upper limit mismatch degree of each continuous interval obtained from S321 is subtracted from the lower limit mismatch degree of each continuous interval obtained from S322. The absolute value of all results is taken, and then the smallest value is taken from the absolute value of all results to obtain the quantitative value of the mismatch between the current photovoltaic power unit's start-up and shutdown status and the set value of the total active power of the complementary integrated power supply in the future time T1. (S330) Seeking operational recommendations for shutting down photovoltaic power generation units: S3310) Manually set the threshold parameter for suggesting shutdown operations; S3320) Set variable v3, and initialize v3 to 1; (S3330) If v3 is less than or equal to the length of the photovoltaic shutdown sequence, then set the original mismatch metric variable, which is equal to the mismatch metric obtained in S320; otherwise, proceed to step S3360. S3340) Calculate the quantified value of the mismatch between the range of sorted v3 in the sequence of possible fluctuations in active power corresponding to the photovoltaic shutdown sequence and the setpoint of the total active power of the complementary integrated power source within the future time T1, including: S3341) Calculate the upper limit mismatch degree between the continuous intervals included in the active power capacity range of the photovoltaic power unit in the future time T1 and the range of sorted v3 in the active power possible fluctuation range sequence corresponding to the photovoltaic shutdown sequence. Subtract the upper limit of each continuous interval included in the active power capacity range of the photovoltaic power unit in the future time T1 from the upper limit of the range of sorted v3 in the active power possible fluctuation range sequence corresponding to the photovoltaic shutdown sequence, and judge the calculation results respectively. If it is greater than 0, the upper limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the upper limit mismatch degree is equal to 0. S3342) Calculate the mismatch degree between the lower limit of the range of the active power capacity of the photovoltaic power unit within the future time T1 and the range of sorted v3 in the active power fluctuation range sequence corresponding to the photovoltaic shutdown sequence. Subtract the lower limit of the range of sorted v3 in the active power fluctuation range sequence corresponding to the photovoltaic shutdown sequence from the lower limit of the active power capacity of the photovoltaic power unit within the future time T1. Judge the calculation results respectively. If it is greater than 0, the lower limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the lower limit mismatch degree is equal to 0. S3343) According to the one-to-one correspondence between the active power capacity range of the photovoltaic power unit in the future T1 time period obtained from S313 and each continuous interval, the upper limit mismatch degree of each continuous interval obtained from S3341 is subtracted from the lower limit mismatch degree of each continuous interval obtained from S3342. The absolute value of all results is taken, and then the smallest value is taken from the absolute value of all results to obtain the quantified value of the mismatch between the range of v3 in the active power possible fluctuation range sequence corresponding to the photovoltaic shutdown sequence and the set value of the total active power of the complementary integrated power supply in the future T1 time period. S3350) Subtract the mismatched metric value obtained from S3343 from the original mismatched metric value variable, and perform the following operations based on the calculation result, including: S3351) If the calculation result is greater than or equal to the judgment threshold parameter set in S3310, then v3 = v3 + 1. If v3 is greater than the length of the photovoltaic shutdown sequence at this time, then jump to step S3360. Otherwise, update the original mismatch metric variable to the mismatch metric obtained in S3343, and jump to step S3340 to continue execution. S3352) If the calculation result is less than the judgment threshold parameter set in S3310, then proceed to step S3360 to continue execution; S3360) Generates operation suggestions based on the value of variable v3, including: S3361) If v3=1, no operation suggestions are generated; S3362) If v3 > 1, then generate a shutdown operation suggestion, suggesting that the photovoltaic units corresponding to sequence 1 to v3-1 in the photovoltaic shutdown sequence be shut down. S340) Recommendations for starting up available but not yet generating photovoltaic units: S3410) Manually set the threshold parameters for recommending power-on operations; S3420) Set variable v4, and initialize v4 to 1; (S3430) If v4 is less than or equal to the photovoltaic unit start-up sequence length, then set the original mismatch metric variable, which is equal to the mismatch metric obtained in S320; otherwise, proceed to step S3460. S3440) Calculate the quantified value of the mismatch between the range of sorted v4 in the sequence corresponding to the possible fluctuation range of active power of the photovoltaic unit start-up sequence and the set value of the total active power of the complementary integrated power supply in the future time T1, including: S3441) Calculate the upper limit mismatch between the continuous intervals included in the active power capacity range of the photovoltaic power unit within the future time T1 obtained in S310 and the range of sorted v4 in the active power possible fluctuation range sequence corresponding to the photovoltaic unit start-up sequence. Subtract the upper limit of each continuous interval included in the active power capacity range of the photovoltaic power unit within the future time T1 from the upper limit of the range of sorted v4 in the active power possible fluctuation range sequence corresponding to the photovoltaic unit start-up sequence, and judge the calculation results respectively. If it is greater than 0, the upper limit mismatch of the continuous interval is equal to the calculation result; otherwise, the upper limit mismatch is equal to 0. S3442) Calculate the mismatch degree between the lower limit of the range of the active power capacity of the photovoltaic power unit within the future time T1 obtained in S310 and the range of sorted v4 in the active power fluctuation range sequence corresponding to the photovoltaic unit start-up sequence. Subtract the lower limit of the range of sorted v4 in the active power fluctuation range sequence corresponding to the photovoltaic unit start-up sequence from the lower limit of the active power capacity of the photovoltaic power unit within the future time T1. Judge the calculation results respectively. If it is greater than 0, the lower limit mismatch degree of the continuous interval is equal to the calculation result; otherwise, the lower limit mismatch degree is equal to 0. S3443) According to the one-to-one correspondence between the active power capacity range of the photovoltaic power unit in the future time T1 obtained from S313 and each continuous interval, the upper limit mismatch degree obtained from S3441 is subtracted from the lower limit mismatch degree obtained from S3442 respectively. The absolute value of all results is taken, and then the smallest value is taken from the absolute value of all results to obtain the quantified value of the mismatch between the range of v4 in the active power possible fluctuation range sequence corresponding to the photovoltaic unit start-up sequence and the set value of the total active power of the complementary integrated power supply in the future time T1. S3450) Subtract the mismatched metric value obtained from S3443 from the original mismatched metric value variable, and perform the following operations based on the calculation result, including: S3451) If the calculation result is greater than or equal to the judgment threshold parameter set in S3410, then v4 = v4 + 1. If v4 is greater than the photovoltaic unit start-up sequence length at this time, then jump to step S3460. Otherwise, update the original mismatch metric variable to the mismatch metric obtained in S3443, and jump to step S3440 to continue execution. S3452) If the calculation result is less than the judgment threshold parameter set in S3410, then proceed to step S3460 to continue execution; S3460) Generate operation suggestions based on the value of variable v4, including: S3461) If v4=1, no operation suggestions are generated; S3462) If v4 > 1, then generate a startup operation suggestion, suggesting that the startup operation be performed on the photovoltaic units corresponding to sequence 1 to v4-1 in the photovoltaic unit startup sequence; Then, the shutdown operation suggestions for photovoltaic units generated by S330 are displayed in an orderly manner. The startup operation suggestions for photovoltaic units generated by S340 are displayed in an orderly manner.

7. The active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage as described in claim 1, characterized in that, The operation of the hydraulic power unit includes: S2100) Determine the unit type of the hydraulic power unit: According to the different active power regulation control states of the generator set, it is divided into single-unit open-loop unit, single-unit closed-loop unit, unit with AGC, and unit without AGC. (S2200) Establish a combined output model for each unit with AGC, and calculate the joint operation zone, joint recommended operation zone, and joint restricted operation zone to determine the current single-unit AGC active power allocation value for each unit; S2300 compares the unit active power target value of the hydraulic power source with the unit joint operation area. When the unit active power target value is included in the unit joint operation area, the unit active power target value is feasible; otherwise, it seeks operation suggestions that make the unit active power target value feasible. The generated operation suggestions are classified and displayed in an orderly manner according to the obtained priority. S2400) Calculate the active power allocation value of a single AGC unit in operation: Calculate the active power allocation value of the unit AGC of the hydraulic power source, and allocate the active power of AGC to each unit in operation. The active power regulation of each closed-loop unit in the S2500 hydraulic power unit determines the set value of the active power of each closed-loop unit. The active power control system of each closed-loop unit in the hydraulic power unit uses the set value of the active power of each unit as the target, calculates the deviation between the actual active power generated by each unit and the set value of the active power of each unit, and outputs a continuous signal to adjust the actual active power generated by each unit according to the calculation result, so that the actual active power generated by each unit tends to the set value of the active power of each unit, and finally stabilizes within the adjustment dead zone range of the set value of the active power of each unit.

8. The active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage as described in claim 1, characterized in that, The operation of the energy storage power unit includes: S3100) calculating the capacity proportion r of the battery charge of each energy storage unit of the energy storage power supply unit i and the overall capacity proportion r of the battery charge of the energy storage power supply unit; S3200) Set the judgment threshold R1'~R6' for the overall capacity ratio of the battery state of charge of the energy storage power unit; where 0 < R1' < R2' < R3' < R4' < R5' < R6' < 1, R1' + R6' = 1, R2' + R5' = 1, R3' + R4' = 1; S3300) determines the overall battery charge status of the energy storage power unit based on the judgment threshold; S3400) Set the threshold values ​​R1~R4 for judging the state of charge capacity ratio of the battery of the energy storage unit; where 0 < R1 < R2 < R3 < R4 < 1, R1 + R4 = 1, R2 + R3 = 1; S3500) Sets auxiliary calculation parameters for the adjustment coefficients of each energy storage unit in the energy storage power unit: S3510) Set four threshold parameters K1, K2, K3, K4, where 0 < K1 < K2 < K3 < K4; S3520) Set the gradient parameter ΔK for the change of the energy storage unit's regulation coefficient, where 0 < ΔK < min[K1, K2 - K1, K3 - K2, K4 - K3], where min[] is the minimum value function. Setting ΔK prevents the dynamic stability of the unit's actual active power from decreasing due to excessive changes in the energy storage unit's regulation coefficient during the regulation process. S3600) Calculate the adjustment coefficient of each energy storage unit in the energy storage power unit: calculate the upward adjustment coefficient of each energy storage unit in the energy storage power unit and calculate the downward adjustment coefficient of each energy storage unit in the energy storage power unit. S3700 performs unit-level AGC allocation of the unit active power target value for energy storage power units: S3710) When the target value of the active power of the energy storage power unit is equal to 0, the set value of the active power of each energy storage unit is equal to 0. (S3720) When the target value of the active power of the energy storage power unit is greater than 0, the set value of the single active power of each energy storage unit is allocated according to the ratio of the product of the upward adjustment coefficient of each energy storage unit and the battery capacity. If the calculation result is greater than the rated capacity of the positive single active power of the energy storage unit, the rated capacity of the positive single active power of the energy storage unit is used as the set value of the single active power. (S3730) When the target value of the active power of the energy storage power unit is less than 0, the set value of the single active power of each energy storage unit is allocated according to the ratio of the product of the downward adjustment coefficient of each energy storage unit and the battery capacity; if the calculation result is less than the rated capacity of the negative single active power of the energy storage unit, the rated capacity of the negative single active power of the energy storage unit is used as the set value of the single active power. The active power control system of each energy storage unit in the S3800 energy storage power unit takes the set value of the active power of a single unit as the target. Based on the deviation between the actual active power generated by a single unit and the set value of the active power of a single unit, it outputs a continuous signal to adjust the actual active power generated by the single unit of the energy storage unit, so that the actual active power generated by the single unit of the energy storage unit tends to the set value of the active power of the single unit, and finally stabilizes within the adjustment dead zone range of the set value of the active power of the single unit. S3900) Calculate the rated active power capacity of the energy storage power unit: S3910) Calculate the upward regulation capability of each energy storage unit in the energy storage power unit; S3920) The upward adjustment energy of each energy storage unit is accumulated to obtain the rated active power capacity of the forward unit of the energy storage power supply unit; S3930) Calculate the downregulation capability of each energy storage unit in the energy storage power unit; S3940) The downward adjustment energy of each energy storage unit is accumulated to obtain the rated capacity of the negative unit active power of the energy storage power unit.

9. The active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage power sources as described in claim 8, characterized in that, The adjustment coefficients of each energy storage unit in the energy storage power unit are corrected as follows: S1610) Correction of upward adjustment coefficient for each energy storage unit in the energy storage power unit: S1611) Initialize and set the upward adjustment coefficient of each energy storage unit in the energy storage power unit. In the formula For energy storage unit i, the upward adjustment coefficient is denoted as . S1612) Adjust the upward adjustment coefficient of each energy storage unit according to a fixed cycle: In the cycle, first calculate the effective threshold parameter of the upward adjustment of each energy storage unit. When 0≤r i <R1 time =0, when R1≤r i <R2 =K1, when R2≤r i When ≤R3 =K2, when R3 < r i When ≤R4 =K3, when R4<r i ≤1 =K4; where r i The percentage of the battery's state-of-charge capacity in energy storage unit i; Then compare and When the absolute value of the difference between the two is less than or equal to ΔK When the absolute value of the difference between the two is greater than ΔK and hour When the absolute value of the difference between the two is greater than ΔK and hour ; S1620) Correction of downward adjustment coefficients for each energy storage unit in the energy storage power unit: S1621) Initialize and set the downward adjustment coefficient of each energy storage unit in the energy storage power unit. In the formula is the downward adjustment coefficient for energy storage unit i; S1622) The downward adjustment coefficient of each energy storage unit is corrected according to a fixed cycle: In the cycle, the effective threshold parameter for downward adjustment of each energy storage unit is first calculated. When 0≤r i <R1 time =K4, when R1≤r i <R2 =K3, when R2≤r i When ≤R3 =K2, when R3 < r i When ≤R4 =K1, when R4 < r i ≤1 =0; Then compare and When the absolute value of the difference between the two is less than or equal to ΔK When the absolute value of the difference between the two is greater than ΔK and hour When the absolute value of the difference between the two is greater than ΔK and hour ; The energy storage power unit also monitors the rated active power capacity of the energy storage power unit in real time: S3910) Calculate the upregulation capability of each energy storage unit in the energy storage power unit, when the effective threshold parameter of the upregulation of the energy storage unit is... When K2 is greater than or equal to K2, the upward adjustment capability of the unit is equal to the rated active power capacity of the unit in the positive direction. When the energy storage unit's upward adjustment takes effect, the threshold parameter becomes effective. When K2 < K2, the upward regulation capacity of the unit is the rated positive single-unit active power capacity of the unit multiplied by K2. Divide by K2 again; S3920) The upward adjustment energy of each energy storage unit is accumulated to obtain the rated active power capacity of the forward unit of the energy storage power supply unit; S3930) Calculate the downregulation capability of each energy storage unit in the energy storage power unit, when the effective threshold parameter for downregulation of the energy storage unit is... When K2 is greater than or equal to K2, the downward adjustment capability of the unit is equal to the rated capacity of the negative single unit active power. When the energy storage unit's downward adjustment takes effect, the threshold parameter becomes effective. When K2 < K2, the downward regulation capacity of the unit is the rated negative single-unit active power capacity multiplied by 1 / 2. Divide by K2 again; S3940) The downward adjustment energy of each energy storage unit is accumulated to obtain the rated capacity of the negative unit active power of the energy storage power unit.

10. The active power regulation method for an integrated power source that complements hydropower, photovoltaic, and energy storage power sources as described in claim 1, characterized in that, The operation of the photovoltaic power unit includes: S4100 generates the possible fluctuation range of active power for each photovoltaic unit within a future time period T1, and calculates the possible fluctuation range of active power per unit of photovoltaic power supply, where T1 is a parameter set to allow sufficient time for possible start-up and shutdown operations of the photovoltaic unit: S4110) If a power prediction system is deployed in the photovoltaic power unit, the possible fluctuation range of the active power of each photovoltaic unit in the future time T1 is calculated using the power prediction function. If a power prediction system is not deployed, the following method is used: (S4121) For photovoltaic power generation units, the current power multiplied by the upper limit prediction parameter is used as the upper limit of the possible fluctuation range of active power in the future time T1, and the current power multiplied by the lower limit prediction parameter is used as the lower limit of the possible fluctuation range of active power, where the upper limit prediction parameter > 1 > the lower limit prediction parameter > 0; the upper limit prediction parameter and the lower limit prediction parameter adopt fixed values ​​or set dynamic parameters according to prior experience. (S4122) For photovoltaic units that do not generate electricity, the possible fluctuation range of active power in the future T1 time period of a generator unit with the same or similar performance shall be used as the possible fluctuation range of active power in the future T1 time period of the unit. S4130) Calculate the possible fluctuation range of the active power of the photovoltaic power unit in the future time T1: sum up the upper limits of the possible fluctuation range of the active power of all generator sets of the photovoltaic power unit in the future time T1, and use it as the upper limit of the possible fluctuation range; sum up the lower limits of the possible fluctuation range of the active power of all generator sets of the photovoltaic power unit in the future time T1, and use it as the lower limit of the possible fluctuation range. S4200 generates start-up and shutdown sequences for photovoltaic units, including: S4210) Generates a shutdown sequence for photovoltaic power generation units. The priority is calculated based on the duration of the unit in power generation mode. The longer the duration of power generation mode, the higher the priority. S4220) Generates a startup sequence of available but non-generating photovoltaic units, with priority calculated based on the duration of the unit's non-generating state. The longer the non-generating state, the higher the priority. S4300 generates sequences of possible active power fluctuation ranges corresponding to start-up and shutdown sequences for photovoltaic units, including: S4310) addresses the potential fluctuation range of active power corresponding to the generation and start-up sequence of photovoltaic units: S4311) Set variable u1, with an initial value of 1; S4312) The possible fluctuation range of active power of photovoltaic power supply unit is added to the possible fluctuation range of active power of unit u1 in the photovoltaic start-up sequence to obtain the range of unit u1 in the possible fluctuation range of active power corresponding to the photovoltaic start-up sequence. The upper limit of the range of unit u1 is equal to the upper limit of the possible fluctuation range of active power of photovoltaic power supply unit plus the upper limit of the possible fluctuation range of active power of unit u1 in the photovoltaic start-up sequence. The lower limit of the range of unit u1 is equal to the lower limit of the possible fluctuation range of active power of photovoltaic power supply unit plus the lower limit of the possible fluctuation range of active power of unit u1 in the photovoltaic start-up sequence. S4313) Determine whether u1 is equal to the photovoltaic start-up sequence length. If u1 is equal to the photovoltaic start-up sequence length, terminate step S4310. Otherwise, execute u1 = u1 + 1 and then continue with the subsequent steps. (S4314) The range of sorted u1-1 in the sequence of possible fluctuation ranges of active power corresponding to the photovoltaic start-up sequence is added to the possible fluctuation range of active power of the photovoltaic unit sorted u1 in the sequence of photovoltaic start-up sequence to obtain the range of sorted u1 in the sequence of possible fluctuation ranges of active power corresponding to the photovoltaic start-up sequence. The upper limit of the range of sorted u1 is equal to the upper limit of the range of sorted u1-1 plus the upper limit of the possible fluctuation range of active power of the unit sorted u1 in the sequence of photovoltaic start-up sequence, and the lower limit of the range of sorted u1 is equal to the lower limit of the range of sorted u1-1 plus the lower limit of the possible fluctuation range of active power of the unit sorted u1 in the sequence of photovoltaic start-up sequence. (S4315) Jump to step S4313 until u1 equals the length of the photovoltaic start-up sequence and ends; S4320) specifies the possible fluctuation range of active power corresponding to the generation and shutdown sequences of photovoltaic units, including: S4321) Set variable u2, with an initial value of 1; (S4322) Subtract the possible fluctuation range of the active power of the photovoltaic power unit from the possible fluctuation range of the active power of the photovoltaic unit ranked u2 in the photovoltaic shutdown sequence to obtain the range of the possible fluctuation range of active power in the sequence corresponding to the photovoltaic shutdown sequence. The upper limit of the range of the ranked u2 is equal to the upper limit of the possible fluctuation range of the active power of the photovoltaic power unit minus the upper limit of the possible fluctuation range of the active power of the unit ranked u2 in the photovoltaic shutdown sequence, and the lower limit of the range of the ranked u2 is equal to the lower limit of the possible fluctuation range of the active power of the photovoltaic power unit minus the lower limit of the possible fluctuation range of the active power of the unit ranked u2 in the photovoltaic shutdown sequence. S4323) Determine whether u2 is equal to the length of the photovoltaic shutdown sequence. If u2 is equal to the length of the photovoltaic shutdown sequence, terminate step S4320; otherwise, execute u2 = u2 + 1 and continue with the subsequent steps. (S4324) Subtract the range of active power fluctuation of unit u2 in the sequence of possible active power fluctuations corresponding to the photovoltaic shutdown sequence from the range of u2-1 in the sequence of possible active power fluctuations corresponding to the photovoltaic shutdown sequence, to obtain the range of u2 in the sequence of possible active power fluctuations corresponding to the photovoltaic shutdown sequence. The upper limit of the range of u2 is equal to the upper limit of the range of u2-1 minus the upper limit of the range of possible active power fluctuations of unit u2 in the sequence of possible active power fluctuations, and the lower limit of the range of u2 is equal to the lower limit of the range of u2-1 minus the lower limit of the range of possible active power fluctuations of unit u2 in the sequence of possible active power fluctuations. (S4325) Jump to step S4323, and continue until u2 equals the length of the photovoltaic shutdown sequence. S4400) Calculates the actual active power generated by the photovoltaic power unit as a calculation factor: S4410) The calculation quantity of the actual active power generated by the photovoltaic power unit is initially set to be equal to the actual active power generated by the unit; S4420) Set the output dead zone of each unit of the photovoltaic power unit and accumulate them to obtain the unit output dead zone of the photovoltaic power unit; S4430) Compare the actual active power generated by the photovoltaic power unit with the actual active power generated by the photovoltaic power unit in the current period according to a fixed period: S4431) If the absolute value of the difference between the two is less than or equal to the output dead zone of the photovoltaic power unit, the actual active power generated by the photovoltaic power unit remains unchanged in the calculation. S4432) If the absolute value of the difference between the two is greater than the output dead zone of the photovoltaic power unit, then the actual active power generated by the photovoltaic power unit is included in the calculation and is equal to the actual active power generated by the photovoltaic power unit in the current period. S4500) The actual active power generated by the photovoltaic power unit is used as a filter value in the calculation of the photovoltaic power unit. The target frequency regulation of the S4600 photovoltaic power unit is: S4610) The grid frequency deviation is equal to the grid rated frequency minus the grid real-time frequency; (S4620) If the absolute value of the grid frequency deviation is less than or equal to the primary frequency regulation threshold, then the unit primary frequency regulation target adjustment of the photovoltaic power unit is equal to 0. (S4630) If the absolute value of the grid frequency deviation is greater than the primary frequency regulation threshold, the target adjustment amount of the primary frequency regulation of the photovoltaic power unit is equal to the actual active power generated by the photovoltaic power unit multiplied by the grid frequency deviation and then multiplied by the photovoltaic primary frequency regulation coefficient given by the grid.

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