WO2024082746A1 - 风电场的频率响应控制方法及装置 - Google Patents

风电场的频率响应控制方法及装置 Download PDF

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Publication number
WO2024082746A1
WO2024082746A1 PCT/CN2023/108874 CN2023108874W WO2024082746A1 WO 2024082746 A1 WO2024082746 A1 WO 2024082746A1 CN 2023108874 W CN2023108874 W CN 2023108874W WO 2024082746 A1 WO2024082746 A1 WO 2024082746A1
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Prior art keywords
power
unit
future
frequency
preset time
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PCT/CN2023/108874
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English (en)
French (fr)
Inventor
左美灵
于迟
徐许
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金风科技股份有限公司
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Publication of WO2024082746A1 publication Critical patent/WO2024082746A1/zh

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Classifications

    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/24—Arrangements for preventing or reducing oscillations of power in networks
    • H02J3/241—The oscillation concerning frequency
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/38—Arrangements for parallely feeding a single network by two or more generators, converters or transformers
    • H02J3/46—Controlling of the sharing of output between the generators, converters, or transformers
    • H02J3/466—Scheduling the operation of the generators, e.g. connecting or disconnecting generators to meet a given demand
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J2300/00—Systems for supplying or distributing electric power characterised by decentralized, dispersed, or local generation
    • H02J2300/20—The dispersed energy generation being of renewable origin
    • H02J2300/28—The renewable source being wind energy
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E10/00—Energy generation through renewable energy sources
    • Y02E10/70—Wind energy
    • Y02E10/76—Power conversion electric or electronic aspects

Definitions

  • the present disclosure generally relates to the field of electric power technology, and more specifically, to a frequency response control method and device for a wind farm.
  • PFR Primary Frequency Control
  • AGC Automatic Generation Control
  • AGC refers to the service that uses automatic control procedures to enable the wind farm to follow the instructions issued by the power dispatching and trading agency within the specified output adjustment range and adjust the power generation output in real time at a certain adjustment rate to meet the frequency and power control requirements of the power system.
  • the primary frequency modulation technology has been gradually rolled out from the initial pilot projects of the Northwest Power Grid and Northeast Power Grid in China. Now it has become a mandatory grid connection requirement, and the technical requirements are becoming more and more stringent. At present, the frequency response is also a necessary function for grid connection testing in the world, and the requirements of power grids in different regions of the world are also different. Therefore, it is necessary to continuously improve the frequency response control method of wind farms to cover various requirements.
  • An exemplary embodiment of the present disclosure provides a frequency response control method and device for a wind farm, which can effectively adjust the output power of the wind farm to meet the frequency regulation demand of the power grid.
  • a frequency response control method for a wind farm comprising: periodically determining a field-wide power adjustment amount that needs to be adjusted by the wind farm due to the frequency and/or frequency change rate of a grid connection point; when in a primary frequency regulation mode, periodically determining an actual field-wide power shortage based on a current field-wide power adjustment amount; determining a single-machine power adjustment amount for each unit based on the current actual field-wide power shortage and a variable pitch adjustable power of each unit in the wind farm for a preset period of time in the future; and issuing a corresponding single-machine power adjustment amount to each unit, respectively, so that each unit adjusts its output power according to the corresponding single-machine power adjustment amount.
  • a frequency response control device for a wind farm comprises: a whole-field power regulation amount determination unit, configured to periodically determine the whole-field power regulation amount that needs to be adjusted by the wind farm due to the frequency and/or frequency change rate of the grid connection point; a whole-field actual power shortage determination unit, configured to periodically determine the whole-field actual power shortage according to the current whole-field power regulation amount when in the primary frequency regulation mode; a single-machine power regulation amount determination unit, configured to determine the single-machine power regulation amount of each unit according to the current whole-field actual power shortage and the variable pitch adjustable power of each unit in the wind farm for a preset time in the future; and a sending unit, configured to send the corresponding single-machine power regulation amount to each unit respectively, so that each unit adjusts the output power according to the corresponding single-machine power regulation amount.
  • a computer-readable storage medium storing a computer program.
  • the processor is prompted to execute the frequency response control method of a wind farm as described above.
  • a frequency response control device for a wind farm comprising: a processor; and a memory storing a computer program, which, when executed by the processor, prompts the processor to execute the frequency response control method for the wind farm as described above.
  • a cascade frequency response control method based on the grid connection point frequency closed loop, power closed loop and small step adjustment is proposed to control the output power of the wind farm, which can effectively meet the grid frequency regulation requirements, significantly improve the control accuracy and shorten the control response time.
  • FIG1 shows a topological structure of a wind farm according to an exemplary embodiment of the present disclosure
  • FIG2 illustrates an example of primary frequency modulation droop control according to an exemplary embodiment of the present disclosure
  • FIG3 illustrates an example of a primary frequency modulation step response indicator according to an exemplary embodiment of the present disclosure
  • FIG. 4 shows a flow chart of a frequency response control method for a wind farm according to an exemplary embodiment of the present disclosure. Process map
  • FIG5 illustrates an example of a primary frequency modulation mode according to an exemplary embodiment of the present disclosure
  • FIG6 shows a flow chart of a frequency response control method of a wind farm according to another exemplary embodiment of the present disclosure
  • FIG. 7 illustrates an example of an inertia response mode according to an exemplary embodiment of the present disclosure
  • FIG8 shows a flow chart of a frequency response control method of a wind farm according to another exemplary embodiment of the present disclosure
  • FIG9 shows a structural block diagram of a frequency response control device for a wind farm according to an exemplary embodiment of the present disclosure.
  • FIG. 1 shows a topological structure of a wind farm according to an exemplary embodiment of the present disclosure.
  • a wind farm level controller eg, the site control system in FIG1
  • a top-level control device can monitor grid connection point data and centrally control all wind turbine generator sets (also referred to as wind turbines or units).
  • the primary frequency regulation action amount can no longer be adjusted downward after reaching 10% of the rated output, and in the case of low-frequency disturbance of the grid, the primary frequency regulation action amount can no longer be adjusted upward after reaching 6% of the rated output (10% and 6% are both recommended setting values).
  • the primary frequency regulation droop characteristic is achieved by setting the frequency and active power broken line function, that is:
  • P represents the full-field power target value that needs to be achieved by primary frequency regulation, in MW; fd represents the primary frequency regulation dead zone, in Hz; fN represents the rated frequency of the power grid system, in Hz; PN represents the rated power, in MW; ⁇ % represents the primary frequency regulation difference coefficient of new energy; P0 represents the initial value of the full-field active power of primary frequency regulation, in MW; f represents the current actual frequency of the power grid.
  • the regulation coefficient is set to 5%
  • the maximum power limit of the primary frequency regulation power upward is set to 6% PN
  • the maximum power limit of the primary frequency regulation power downward is set to 10% PN
  • the droop curve of the wind farm participating in the primary frequency regulation of the power grid can be shown in Figure 2.
  • t 0 represents the start time
  • t d represents the start time
  • t up represents the response time
  • t s represents the adjustment time
  • PN represents the rated power
  • ⁇ P represents the target power adjustment amount.
  • FIG4 shows a flow chart of a frequency response control method of a wind farm according to an exemplary embodiment of the present disclosure.
  • the frequency response control method of a wind farm may be executed by a field-level controller of the wind farm.
  • the field-level controller may be a Voltage/Var Management Platform (VMP).
  • VMP Voltage/Var Management Platform
  • a wind farm may include multiple wind turbines, which are connected to the power grid in an appropriate manner.
  • step S101 the wind farm-wide power regulation amount that needs to be regulated due to the frequency and/or frequency change rate of the grid connection point is periodically determined.
  • the total power adjustment amount that needs to be adjusted by the wind farm is the active power increment that needs to be adjusted by the wind farm. It should be understood that the total power adjustment amount that needs to be adjusted by the wind farm can be greater than 0 or less than 0. If the total power adjustment amount that needs to be adjusted by the wind farm is greater than 0, the wind farm needs to increase its active power output, and if the total power adjustment amount that needs to be adjusted by the wind farm is less than 0, the wind farm needs to reduce its active power output.
  • the total power regulation amount may be: the total power regulation amount of the primary frequency modulation for realizing the primary frequency modulation.
  • the total power regulation amount may be: the sum of the AGC total power regulation amount for realizing AGC and the total power regulation amount of the primary frequency modulation for realizing the primary frequency modulation.
  • the total power regulation amount that needs to be adjusted by the wind farm due to the frequency and/or frequency change rate of the grid connection point can be periodically determined from the beginning of the current grid frequency disturbance (for example, the frequency of the grid connection point exceeds the frequency dead zone or the frequency change rate of the grid connection point exceeds the frequency change rate dead zone) to the end of the current grid frequency disturbance.
  • the period for determining the whole-field power adjustment amount that needs to be adjusted by the wind farm may be 20 ms.
  • step S102 in the case of being in the primary frequency modulation mode, the actual shortfall of the whole-field power is periodically determined according to the current whole-field power adjustment amount.
  • the current wind farm power target value that needs to be adjusted can be determined based on the current wind farm power adjustment amount, and then the difference between the current wind farm power target value and the current wind farm power actual value can be determined as the wind farm power actual shortage.
  • the initial value of the total power at the beginning of the grid frequency disturbance can be compared with the current total power
  • the sum of the field power adjustment amounts is determined as the full-field power target value that the wind farm currently needs to adjust to.
  • the actual power value of the entire wind farm may be the actual power of the grid connection point of the wind farm or the sum of the actual powers of each wind turbine generator set in the wind farm.
  • the period for determining the actual shortfall of the entire power may be 20 ms.
  • step S103 the individual power adjustment amount of each unit is determined according to the current actual power shortage of the entire farm and the pitch adjustable power of each unit of the wind farm for a preset time period in the future.
  • the length of the preset time length may be less than 5 seconds, for example, the preset time length may be 1 second or 2 seconds.
  • variable pitch adjustable power of each unit for a preset time in the future includes: the variable pitch increase power of the unit for the preset time in the future and the variable pitch decrease power of the unit for the preset time in the future.
  • variable pitch power OneCycleUpPower of the unit in the future preset time period can be determined based on the preset variable pitch power per unit time of the unit and the length of the preset time; otherwise, the variable pitch power of the unit in the future preset time period can be 0.
  • the maximum power limit of the unit refers to: the maximum power that the unit can reach under the wind conditions and operating conditions at that time. Because it may be in a power-limited state, the real-time power may be less than this maximum value. This maximum value may be the rated power, which may be less than the rated power.
  • variable pitch power that can be increased for a preset period of time in the future for a unit whose pitch angle has not reached the minimum pitch angle and whose power has not reached the maximum value of the limited power can be: the product of the preset variable pitch power that can be increased per unit time of the unit (for example, the preset variable pitch power that can be increased for 1s), the preset time length, and the first conversion deviation coefficient.
  • the pitch reduction power of the unit for a preset time period in the future can be determined based on the preset pitch reduction power per unit time of the unit and the length of the preset time; otherwise, the pitch reduction power of the unit for the preset time period in the future may be 0.
  • the pitch reduction power that can be achieved in the future preset time period is: the product of the preset pitch reduction power per unit time of the unit, the preset time period and the second conversion deviation coefficient.
  • the unit's variable pitch power OneCycleUpPower for a preset time in the future the preset 1s adjustment capability ExecutionRate ⁇ single-step cycle length CloseLoopCycle ⁇ the first conversion deviation coefficient, where, The preset 1s adjustment capability ExecutionRate is the preset 1s pitch change power increase, and the single-step cycle length CloseLoopCycle is the preset duration.
  • the first conversion deviation coefficient may be 0.8.
  • the unit's variable pitch power reduction for a preset period of time in the future OneCycleDownPower the preset 1s adjustment capability ExecutionRate ⁇ the single-step cycle duration CloseLoopCycle ⁇ the second conversion deviation coefficient, wherein the preset 1s adjustment capability ExecutionRate is the preset 1s variable pitch power reduction, and the single-step cycle duration CloseLoopCycle is the preset duration.
  • the second conversion deviation coefficient can be 0.8.
  • the field-wide power increase amount for a preset period in the future can be determined based on the field-wide power increase standby power for a preset period in the future and the current actual power shortage of the entire field, and the single-unit power adjustment amount of each unit can be determined based on the field-wide power increase amount for the preset period in the future.
  • the full-scale up-regulated standby power for a preset time in the future is the sum of the variable pitch power of the units whose pitch angles have not reached the minimum pitch angle and whose power has not reached the maximum power limit for a preset time in the future.
  • the full-scale up-regulated standby power for a preset time in the future can be:
  • the actual field-wide power shortfall may be determined as the field-wide power increase amount for the preset period of time in the future; when the field-wide increased standby power for a preset period of time in the future is less than the actual field-wide power shortfall, the field-wide increased standby power for a preset period of time in the future may be determined as the field-wide power increase amount for the preset period of time in the future.
  • the single-unit power regulation amount of the unit can be determined based on the product of the unit's upward adjustment weight coefficient and the total power increase amount in the future preset time period. For example, for each unit whose pitch angle has not reached the minimum pitch angle and whose power has not reached the maximum power limit, the product of the unit's upward adjustment weight coefficient and the total power increase amount in the future preset time period and the sum of the deviation correction value can be used as the single-unit power regulation amount of the unit.
  • the upward adjustment weight coefficient of each unit can be: the ratio between the variable pitch increase power capability of the unit and the sum of the variable pitch increase power capabilities of each unit, and the variable pitch increase power capability of the unit is the product of the difference between the average pitch angle of the unit and the minimum pitch angle and the rated power of the unit.
  • the sum of the variable pitch increase power capabilities of each unit refers to the variable pitch increase power of each unit whose pitch angle has not reached the minimum pitch angle and whose power has not reached the maximum power limit. The sum of abilities.
  • the average pitch angle of the unit is: the average value of the pitch angles of all blades of the unit.
  • the variable pitch power adjustment capacity of the unit OneCapacity[i] (average pitch angle ⁇ i – minimum pitch angle ⁇ min ) ⁇ rated power P i rated ; the sum of the variable pitch power adjustment capacity of each unit G TotalUPPitch is The upward adjustment weight coefficient Proportion[i] of the unit is
  • the field-wide power reduction amount for a preset period in the future can be determined based on the field-wide power reduction standby power for a preset period in the future and the current actual power shortage of the entire field, and the single-machine power adjustment amount of each unit can be determined based on the field-wide power reduction amount for the preset period in the future.
  • the full field down-regulated standby power for a preset time in the future is the sum of the variable pitch power reduction of the units whose pitch angles have not reached the standby pitch angle and whose power is not lower than the minimum power limit value for a preset time in the future.
  • the full field up-regulated standby power for a preset time in the future can be:
  • the actual shortage of the field-wide power may be determined as the field-wide power reduction amount for the preset period of time in the future; when the field-wide reserve power reduction for a preset period of time in the future is greater than the actual shortage of the field-wide power, the field-wide reserve power reduction for a preset period of time in the future may be determined as the field-wide power reduction amount for the preset period of time in the future.
  • the single-unit power regulation amount of the unit can be determined based on the product of the downward adjustment weight coefficient of the unit and the total power reduction amount in the future preset time period. For example, for each unit whose pitch angle has not reached the standby pitch angle and whose power is not lower than the minimum power limit, the product of the downward adjustment weight coefficient of the unit and the total power reduction amount in the future preset time period and the sum of the deviation correction value can be used as the single-unit power regulation amount of the unit.
  • the downward adjustment weight coefficient of each unit can be: the ratio of the variable pitch downward adjustment power capability of the unit to the sum of the variable pitch downward adjustment power capabilities of each unit, and the variable pitch downward adjustment power capability of the unit is the product of the difference between the standby pitch angle and the average pitch angle of the unit and the rated power of the unit.
  • the sum of the variable pitch downward adjustment power capabilities of each unit refers to the total power reduction capability of each unit.
  • the deviation correction value of each unit may be: the difference between the current actual power value of the unit and the initial power value P0 of the unit when the current grid frequency disturbance begins.
  • the present disclosure takes into account that in the related art, the capacities of some wind farm units vary greatly.
  • the use of existing algorithms for allocation based on the adjustable power of the units will result in excessive adjustment depth for small-capacity units, resulting in excessive response time and failure to meet grid requirements.
  • an algorithm for allocation based on the pitch angle is used. Allocation is performed based on the adjustable angle of the unit. The adjustment depth will not be determined by the difference in rated power, but will be determined based on the blade angle of the unit. In this way, the adjustment amount of each unit will vary greatly, but the relative adjustment depth will not expand, which can shorten the normal response time.
  • the algorithm for allocation based on the pitch angle reduces the adjustable power margin deviation, improves control accuracy, and has universal applicability both domestically and internationally.
  • the present disclosure takes into account that the theoretical power calculation accuracy in the related art is not high enough, and the frequency response control adjustable margin is calculated based on the ultra-short-term wind turbine predicted theoretical power, so there will be deviations in the control process.
  • improving the response accuracy is a must.
  • the ultra-short-term wind turbine predicted theoretical power is only used as a reference for the upstream power grid regulation, and is not used as a basis for specific control, thereby improving the control response accuracy.
  • the present disclosure takes into account the AGC equipment in the related art, for example, after the low-frequency standby function of the Energy Management Platform (EMP) is put into use, the adjustable power sent to the dispatcher in the EMP is far different from the adjustable power calculated by the primary frequency regulation, resulting in the primary frequency regulation response not meeting the grid requirements. Therefore, according to the exemplary embodiment of the present disclosure, when the theoretical power calculated by the EMP and the frequency response device VMP is far apart, the actual control is not affected, and the response can still be guaranteed to be in place to meet the grid requirements.
  • EMP Energy Management Platform
  • step S104 the corresponding single-machine power adjustment amount is sent to each unit so that each unit The group adjusts the output power according to the corresponding single-machine power adjustment amount.
  • the frequency response control method of the wind farm may further include: returning to execute step S103. It should be understood that each time the execution of step S103 is returned, the actual power shortage of the entire farm and the variable pitch adjustable power of each unit in the wind farm for the preset time in the future are the latest updated.
  • the process returns to step S103.
  • the process returns to step S103.
  • the power is adjusted with a small step and multiple iterations.
  • the power is adjusted with a small step and multiple iterations, that is, the planned adjustment amount is split according to a certain step, and the single machine adjustment amount is sent to the control mode of the unit in a periodic and multiple iterations of the step.
  • the grid connection point frequency and frequency change rate closed loop is the outermost loop control (i.e., the first loop control), which is the amount that directly causes the target value to change;
  • the grid connection point power or the total active power of the unit is the middle loop control (i.e., the second loop control), which is the amount that follows the target value of the first loop and is adjusted at any time.
  • the second loop periodically detects whether the current power meets the target value of the first loop; the small step and multiple iterations control is the innermost loop control (i.e., the third loop control), which is the most frequent action.
  • the second loop determines the actual shortage of the total power of the whole field, it is divided according to the step (i.e., the preset duration mentioned above) in the third loop, and then controlled according to each step control amount.
  • the single step control cycle ends, it returns to the second loop, and repeats this cycle until the second loop meets the control dead zone range. Finally, when the first loop enters the frequency and frequency change rate dead zone, the control is completely ended.
  • FIG5 shows an example of a primary frequency modulation mode according to an exemplary embodiment of the present disclosure. That is, the control flow from the second loop to the third loop.
  • the core idea of the "small step control calculation” is: for units with pitch angle adjustment capability, calculate the maximum power that can be adjusted in a single cycle according to the pre-designed adjustment speed, and then iteratively divide and execute according to the maximum power that can be adjusted in a single cycle according to actual needs.
  • the core idea of the "paddle angle ratio algorithm” is: the unit will definitely change the pitch when the power is limited, the ratio of the pitch angle is approximately proportional to the power limit depth, and the pitch will not change during free power generation. Therefore, based on the positive proportional relationship, the weight ratio of each wind turbine to adjust the power under the current pitch angle can be calculated, and then the power is adjusted according to the weight to achieve the purpose of distribution control.
  • FIG6 shows a flow chart of a frequency response control method of a wind farm according to another exemplary embodiment of the present disclosure.
  • step S201 the frequency and frequency change rate of the grid connection point are detected.
  • step S202 the wind farm-wide power regulation amount that needs to be regulated due to the frequency and/or frequency change rate of the grid connection point is periodically determined.
  • step S203 the active power regulation mode that the wind farm needs to enter is periodically determined.
  • the active power regulation mode that the wind farm needs to enter can be determined based on the frequency and frequency change rate of the grid connection point.
  • the period for determining the active power regulation mode that the wind farm needs to enter may be 20 ms.
  • an appropriate judgment strategy can be used to determine whether the wind farm needs to enter the active power regulation mode of the primary frequency regulation mode, the inertia response mode, or the rapid power reduction mode.
  • step S204 in response to the active power regulation mode to be entered being the primary frequency modulation mode, the primary frequency modulation mode is entered.
  • step S205 in response to the active power regulation mode to be entered being the inertia response mode, the inertia response mode is entered.
  • step S206 in response to the active power regulation mode to be entered being the rapid power reduction mode, the rapid power reduction mode is entered. It should be understood that a wind farm can only be in one active power regulation mode at the same time.
  • step S207 when in the primary frequency modulation mode, the actual shortfall of the full-field power is periodically determined according to the current full-field power adjustment amount.
  • step S208 the individual power adjustment amount of each unit is determined according to the current actual power shortage of the entire farm and the pitch adjustable power of each unit of the wind farm for a preset time period in the future.
  • step S209 the corresponding single-machine power adjustment amount is issued to each unit respectively, so that each unit adjusts the output power according to the corresponding single-machine power adjustment amount. If the preset time has passed since the last single-machine power adjustment amount was issued, the process returns to step S208.
  • primary frequency modulation is implemented in a three-loop cascade control manner, and inertia response and rapid power reduction are controlled in a closed loop according to the grid connection point frequency.
  • the single-machine power adjustment amount of each unit can be determined by appropriate means, and the corresponding single-machine power adjustment amount can be issued to each unit respectively, so that each unit adjusts the output power according to the corresponding single-machine power adjustment amount. This disclosure will not be repeated here.
  • the individual power adjustment amount of each unit can be determined by appropriate means, and the corresponding individual power adjustment amount can be sent to each unit respectively, so that each unit The unit adjusts the output power according to the corresponding single-machine power regulation amount.
  • the unit can consume the reducible active power through the braking resistor in the fast power reduction mode, which will not be elaborated in this disclosure.
  • the frequency response control method of a wind farm may also include: when the grid frequency change rate exceeds the frequency change rate dead zone and the grid frequency does not exceed the frequency dead zone, if the grid frequency change rate returns to the frequency change rate dead zone before the inertia response can last, then the preset single-machine power adjustment amount is issued to each unit respectively; when the grid frequency change rate exceeds the frequency change rate dead zone and the grid frequency does not exceed the frequency dead zone, if the grid frequency change rate does not return to the frequency change rate dead zone when the inertia response can last, then the preset single-machine power adjustment amount is issued to each unit respectively.
  • the present disclosure makes corresponding adjustments to the inertia response.
  • Each inertia response regardless of whether there is a frequency modulation followed by a small deltP (i.e., the preset single-machine power adjustment amount) and a slow rate of the frequency modulation are used for transition, and then the control is terminated.
  • the control is terminated, that is, the "exit process allocation" in Figure 8 is executed.
  • the small deltP there is a short section of instructions very close to the target power in the process of returning to the mode before the frequency modulation. This is the small deltP.
  • the small deltP control time is reached, the target value and the enable flag are directly cleared to 0 to terminate the control.
  • 1 represents a frequency modulation to increase power
  • -1 represents a frequency modulation to reduce power
  • the number represents the working condition.
  • the inertia response is forced to return to the frequency modulation mode to end the control because the control inertia time has expired or the disturbance has ended. Specifically, it can be divided into the following situations: 1. The frequency change rate exceeds the dead zone, and the frequency does not exceed the dead zone: when the frequency change rate does not exceed the inertia response duration, it returns to the dead zone, and then ends with the small deltP; 2.
  • the frequency change rate exceeds the dead zone, and the frequency does not exceed the dead zone: when the frequency change rate exceeds the inertia response duration and does not return to the dead zone, it ends with the small deltP according to the duration; 3.
  • the frequency change rate exceeds the dead zone, and the frequency also exceeds the dead zone: when the frequency change rate does not reach the duration, it returns to the dead zone, and then follows the frequency modulation instruction, and then ends with the small deltP; 4.
  • the frequency change rate exceeds the dead zone, and the frequency also exceeds the dead zone: when the frequency change rate exceeds the duration and does not return to the dead zone, it follows the duration, follows the frequency modulation instruction, and then ends with the small deltP.
  • the frequency response control method of the wind farm when in the rapid power reduction mode, may also include: in the recovery stage, controlling the units of the wind farm with rapid power reduction capability according to the rapid power reduction recovery method, and controlling the units of the wind farm without rapid power reduction capability according to the primary frequency regulation recovery method.
  • the fast power reduction condition has a matching response rate of FastPwrRateSet.
  • the actual shortfall that needs to be adjusted upward is based on the current power. The actual situation is determined.
  • FIG8 shows a flow chart of a frequency response control method for a wind farm according to another exemplary embodiment of the present disclosure.
  • the CP method refers to determining the theoretical power of the unit based on the current pitch angle and wind speed of the unit using a theoretical power table.
  • the comprehensive instruction is the total power adjustment amount that needs to be adjusted by the wind farm.
  • the problem of long frequency control response time in wind farms can be solved; the accuracy of frequency control throughout the field can be improved; the dependence of frequency response control on theoretical power can be reduced; and the problem of unqualified frequency control due to differences in algorithms between different control devices can be avoided.
  • FIG9 shows a structural block diagram of a frequency response control device for a wind farm according to an exemplary embodiment of the present disclosure.
  • the frequency response control device of a wind farm includes: a whole-farm power regulation amount determination unit 101 , a whole-farm power actual shortage determination unit 102 , a single-machine power regulation amount determination unit 103 , and a sending unit 104 .
  • the whole field power adjustment amount determination unit 101 is configured to periodically determine the power adjustment amount of the grid-connected The total power regulation amount that needs to be regulated by the wind farm caused by the frequency and/or frequency change rate at the point.
  • the actual shortfall of power in the entire field determining unit 102 is configured to periodically determine the actual shortfall of power in the entire field according to the current power adjustment amount in the entire field when in the primary frequency modulation mode.
  • the single-machine power regulation amount determination unit 103 is configured to determine the single-machine power regulation amount of each unit according to the current actual power shortage of the entire farm and the pitch adjustable power of each unit of the wind farm for a preset time in the future.
  • the issuing unit 104 is configured to issue the corresponding single-machine power adjustment amount to each unit respectively, so that each unit adjusts the output power according to the corresponding single-machine power adjustment amount.
  • the single-machine power adjustment amount determination unit 103 can also be configured to: when a preset time has passed since the last single-machine power adjustment amount was sent, determine the single-machine power adjustment amount of each unit according to the current actual power shortage of the entire field and the variable pitch adjustable power of each unit in the wind farm within a preset time in the future.
  • the frequency response control device may also include: an active regulation mode determination unit (not shown), the active regulation mode determination unit being configured to periodically determine the active regulation mode that the wind farm needs to enter based on the frequency and frequency change rate of the grid connection point; in response to the active regulation mode that needs to be entered being a primary frequency modulation mode, entering the primary frequency modulation mode; in response to the active regulation mode that needs to be entered being an inertia response mode, entering the inertia response mode; in response to the active regulation mode that needs to be entered being a rapid power reduction mode, entering the rapid power reduction mode, wherein the wind farm can only be in one active regulation mode at the same time.
  • an active regulation mode determination unit being configured to periodically determine the active regulation mode that the wind farm needs to enter based on the frequency and frequency change rate of the grid connection point
  • the active regulation mode that needs to be entered being a primary frequency modulation mode, entering the primary frequency modulation mode
  • in response to the active regulation mode that needs to be entered being an inertia response mode, entering the in
  • the adjustable pitch power of the unit in the future preset time may include: the adjustable pitch power of the unit in the future preset time and the adjustable pitch power of the unit in the future preset time; the adjustable pitch power of the unit in the future preset time whose pitch angle has not reached the minimum pitch angle and whose power has not reached the maximum value of the limited power is: the product of the preset adjustable pitch power of the unit per unit time, the preset time and the first conversion deviation coefficient; the adjustable pitch power of the unit in the future preset time whose pitch angle has not reached the standby pitch angle and whose power is not lower than the minimum value of the limited power is: the product of the preset adjustable pitch power of the unit per unit time, the preset time and the second conversion deviation coefficient.
  • the single-machine power regulation amount determination unit 103 can be configured as follows: when the current actual power shortage of the entire field is greater than 0, the total power increase amount for the preset time period in the future is determined according to the total power increase amount for the preset time period in the future and the current actual power shortage of the entire field, and the single-machine power regulation amount of each unit is determined based on the total power increase amount for the preset time period in the future; when the current actual power shortage of the entire field is less than 0, the single-machine power regulation amount of each unit is determined according to the total power decrease amount for the preset time period in the future.
  • the power and the current actual shortfall of the whole-field power are used to determine the amount of power reduction for the whole-field in the future preset time, and based on the amount of power reduction for the whole-field in the future preset time, the power adjustment amount of each unit is determined, wherein the whole-field upward adjustment standby power for the future preset time is the sum of the power increase of each unit by the pitch of each unit in the
  • the single-machine power regulation amount determination unit 103 can be configured as: when the field-wide power increase standby power for a preset period of time in the future is greater than the actual power shortage of the field-wide power, the actual power shortage of the field-wide power is determined as the field-wide power increase amount for the preset period of time in the future; when the field-wide power increase standby power for a preset period of time in the future is less than the actual power shortage of the field-wide power, the field-wide power increase standby power for a preset period of time in the future is determined as the field-wide power increase amount for the preset period of time in the future.
  • the single-machine power adjustment amount determination unit 103 can be configured as: when the field-wide power reduction standby power for a preset period of time in the future is less than the actual power shortage of the field-wide power, the actual power shortage of the field-wide power is determined as the field-wide power reduction amount for a preset period of time in the future; when the field-wide power reduction standby power for a preset period of time in the future is greater than the actual power shortage of the field-wide power, the field-wide power reduction standby power for a preset period of time in the future is determined as the field-wide power reduction amount for a preset period of time in the future.
  • the single-machine power regulation amount determination unit 103 can be configured as: for each unit whose pitch angle has not reached the minimum pitch angle and whose power has not reached the maximum power limit, the product of the unit's increase weight coefficient and the total power increase amount for a preset period of time in the future and the sum of the deviation correction value is used as the single-machine power regulation amount of the unit, wherein the increase weight coefficient of each unit is: the ratio of the unit's variable pitch increase power capability to the sum of the variable pitch increase power capabilities of all units, and the unit's variable pitch increase power capability is the product of the difference between the unit's average pitch angle and the minimum pitch angle and the rated power of the unit.
  • the single-machine power regulation amount determination unit 103 can be configured as: for each unit whose pitch angle has not reached the standby pitch angle and whose power is not lower than the minimum power limit, the product of the unit's downward adjustment weight coefficient and the total power reduction amount for a preset period of time in the future and the sum of the deviation correction value is used as the single-machine power adjustment amount of the unit, wherein the downward adjustment weight coefficient of each unit is: the ratio of the unit's variable pitch downward adjustment power capability to the sum of the variable pitch downward adjustment power capabilities of all units, and the unit's variable pitch downward adjustment power capability is the product of the difference between the unit's standby pitch angle and the average pitch angle and the rated power of the unit.
  • the deviation correction value of each unit may be: the difference between the current actual power value of the unit and the initial power value of the unit when the current grid frequency disturbance begins.
  • the frequency response control device may also include: an inertia response control unit (not shown), the inertia response control unit being configured to, when in the inertia response mode, if the grid frequency change rate exceeds the frequency change rate dead zone and the grid frequency does not exceed the frequency dead zone, if the grid frequency change rate returns to the frequency change rate dead zone before the inertia response can last, then send a preset single-machine power adjustment amount to each unit respectively; if the grid frequency change rate exceeds the frequency change rate dead zone and the grid frequency does not exceed the frequency dead zone, if the grid frequency change rate does not return to the frequency change rate dead zone when the inertia response can last, then send a preset single-machine power adjustment amount to each unit respectively.
  • an inertia response control unit not shown
  • the inertia response control unit being configured to, when in the inertia response mode, if the grid frequency change rate exceeds the frequency change rate dead zone and the grid frequency does not exceed the frequency dead
  • the frequency response control device may also include: a rapid power reduction control unit (not shown), which is configured to control the units of the wind farm with rapid power reduction capability in accordance with a rapid power reduction recovery method during the recovery phase when in the rapid power reduction mode, and control the units of the wind farm without rapid power reduction capability in accordance with a primary frequency regulation recovery method.
  • a rapid power reduction control unit (not shown), which is configured to control the units of the wind farm with rapid power reduction capability in accordance with a rapid power reduction recovery method during the recovery phase when in the rapid power reduction mode, and control the units of the wind farm without rapid power reduction capability in accordance with a primary frequency regulation recovery method.
  • the frequency response control device may be arranged in a controller of a wind farm.
  • the various units in the frequency response control device of the wind farm can be implemented as hardware components and/or software components.
  • Those skilled in the art can implement the various units, for example, using a field programmable gate array (FPGA) or an application specific integrated circuit (ASIC) according to the processing performed by the various defined units.
  • FPGA field programmable gate array
  • ASIC application specific integrated circuit
  • An exemplary embodiment of the present disclosure provides a computer-readable storage medium storing a computer program, which, when executed by a processor, causes the processor to execute the frequency response control method of a wind farm as described in the above exemplary embodiment.
  • the computer-readable storage medium is any data storage device that can store data read by a computer system. Examples of computer-readable storage media include: read-only memory, random access memory, read-only optical disk, magnetic tape, floppy disk, optical data storage device, and carrier wave (such as data transmission through the Internet via a wired or wireless transmission path).
  • a frequency response control device of a wind farm includes: a processor (not shown) and a memory (not shown), wherein the memory stores a computer program, and when the computer program is executed by the processor, the processor is prompted to execute the frequency response control method of the wind farm as described in the above exemplary embodiment.
  • the frequency response control device may be arranged in a controller of a wind farm.

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Abstract

提供了一种风电场的频率响应控制方法及装置。所述频率响应控制方法包括：周期性地确定由并网点的频率和/或频率变化率引起的需要风电场调节的全场功率调节量；在处于一次调频模式的情况下，周期性地根据当前的全场功率调节量确定全场功率实际缺额；根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量；分别向各台机组下发对应的单机功率调节量，以使各台机组按照对应的单机功率调节量调整输出功率。

Description

风电场的频率响应控制方法及装置 技术领域
本公开总体说来涉及电力技术领域，更具体地讲，涉及一种风电场的频率响应控制方法及装置。
背景技术
一次调频(Primary Frequency Control，PFR)指当电力系统(例如，电网)的频率偏离目标频率时，风电场通过控制系统的自动反应，调整有功出力以减少电力系统的频率偏差的控制功能。自动发电控制(Automatic Generation Control，AGC)指通过自动控制程序，使风电场在规定的出力调整范围内，跟踪电力调度交易机构下发的指令，按照一定的调节速率实时调整发电出力，以满足电力系统频率和功率控制要求的服务。
一次调频技术从最初的国内西北电网、东北电网等试点陆续铺开，到现在已经变成强制性的并网要求，且技术要求越来越严苛。目前国际中频率响应也都是入网测试必须功能，且国际不同区域电网要求也各不相同。因此，需要不断改进风电场的频率响应控制方法，以覆盖各种要求。
发明内容
本公开的示例性实施例在于提供一种风电场的频率响应控制方法及装置，能够有效调节风电场的输出功率来满足电网调频需求。
根据本公开实施例的第一方面，提供一种风电场的频率响应控制方法，包括：周期性地确定由并网点的频率和/或频率变化率引起的需要风电场调节的全场功率调节量；在处于一次调频模式的情况下，周期性地根据当前的全场功率调节量确定全场功率实际缺额；根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量；分别向各台机组下发对应的单机功率调节量，以使各台机组按照对应的单机功率调节量调整输出功率。
根据本公开实施例的第二方面，提供一种风电场的频率响应控制装置， 包括：全场功率调节量确定单元，被配置为周期性地确定由并网点的频率和/或频率变化率引起的需要风电场调节的全场功率调节量；全场功率实际缺额确定单元，被配置为在处于一次调频模式的情况下，周期性地根据当前的全场功率调节量确定全场功率实际缺额；单机功率调节量确定单元，被配置为根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量；下发单元，被配置为分别向各台机组下发对应的单机功率调节量，以使各台机组按照对应的单机功率调节量调整输出功率。
根据本公开实施例的第三方面，提供一种存储有计算机程序的计算机可读存储介质，当所述计算机程序被处理器执行时，促使所述处理器执行如上所述的风电场的频率响应控制方法。
根据本公开实施例的第四方面，提供一种风电场的频率响应控制装置，所述频率响应控制装置包括：处理器；存储器，存储有计算机程序，当所述计算机程序被处理器执行时，促使所述处理器执行如上所述的风电场的频率响应控制方法。
根据本公开的示例性实施例的风电场的频率响应控制方法及装置，提出了基于并网点频率闭环、功率闭环、小步长调节的级联频率响应控制方式来控制风电场的输出功率，能够有效满足电网调频需求，较大幅度地提高控制精度，缩短控制响应时间。
此外，还可进一步在并网点频率和功率双闭环的基础上，叠加功率小步长多次迭代调节，实现一次调频三环级联控制方式。
将在接下来的描述中部分阐述本公开总体构思另外的方面和/或优点，还有一部分通过描述将是清楚的，或者可以经过本公开总体构思的实施而得知。
附图说明
通过结合附图，从实施例的下面描述中，本公开这些和/或其它方面及优点将会变得清楚。
图1示出根据本公开的示例性实施例的风电场的拓扑结构；
图2示出根据本公开的示例性实施例的一次调频下垂控制的示例；
图3示出根据本公开的示例性实施例的一次调频阶跃响应指标的示例；
图4示出根据本公开的示例性实施例的风电场的频率响应控制方法的流 程图；
图5示出根据本公开的示例性实施例的一次调频模式的示例；
图6示出根据本公开的另一示例性实施例的风电场的频率响应控制方法的流程图；
图7示出根据本公开的示例性实施例的惯量响应模式的示例；
图8示出根据本公开的另一示例性实施例的风电场的频率响应控制方法的流程图；
图9示出根据本公开的示例性实施例的风电场的频率响应控制装置的结构框图。
具体实施方式
现将详细参照本公开的实施例，所述实施例的示例在附图中示出，其中，相同的标号始终指的是相同的部件。以下将通过参照附图来说明所述实施例，以便解释本公开。
图1示出根据本公开的示例性实施例的风电场的拓扑结构。
参照图1，风电场场级控制器(例如，图1中的场站控制系统)作为顶层控制设备，可监控并网点数据，并集中控制所有风力发电机组(也简称为风机、机组)。
作为示例，风电场电网高频扰动情况下，一次调频动作量达10％额定出力后可不再向下调节，电网低频扰动情况下，一次调频动作量达6％额定出力后可不再向上调节(10％、6％均为推荐设定值)。一次调频下垂特性通过设定频率与有功功率折线函数实现，即：
其中，P表示一次调频需要达到的全场功率目标值，单位为MW；fd表示一次调频死区，单位为Hz；fN表示电网系统额定频率，单位为Hz；PN表示额定功率，单位为MW；δ％表示新能源一次调频调差系数；P0表示一次调频全场有功初始值，单位为MW；f表示电网当前的实际频率。
例如，在一次调频死区设定0.05Hz，调差系数设定5％，一次调频功率上调节最大功率限幅设定为6％PN，一次调频功率下调节最大功率限幅设定为10％PN的情况下，风电场参与电网一次调频的下垂曲线可如图2所示。
图3示出根据本公开的示例性实施例的一次调频阶跃响应指标的示例，t0表示起始时间，td表示启动时间，tup表示响应时间，ts表示调节时间，PN表示额定功率，ΔP表示目标功率调节量。
图4示出根据本公开的示例性实施例的风电场的频率响应控制方法的流程图。
作为示例，根据本公开的示例性实施例的风电场的频率响应控制方法可由风电场的场级控制器执行，例如，该场级控制器可为无功管理平台(Voltage/Var Management Platform，VMP)。
风电场可包括多台风力发电机组。风电场的风力发电机组通过适当的方式接入电网。
参照图4，在步骤S101，周期性地确定由并网点的频率和/或频率变化率引起的需要风电场调节的全场功率调节量。
需要风电场调节的全场功率调节量即需要风电场调节的有功功率增量。应该理解，需要风电场调节的全场功率调节量可大于0或小于0，需要风电场调节的全场功率调节量大于0即需要风电场增大有功功率输出，需要风电场调节的全场功率调节量小于0即需要风电场降低有功功率输出。
作为示例，全场功率调节量可为：用于实现一次调频的一次调频全场功率调节量。作为示例，在当前还需要对风电场进行自动发电控制AGC的情况下，全场功率调节量可为：用于实现AGC的AGC全场功率调节量与用于实现一次调频的一次调频全场功率调节量之和。
作为示例，可从本次电网频率扰动(例如，并网点的频率超过频率死区或并网点的频率变化率超过频率变化率死区)开始至本次电网频率扰动结束，周期性地确定由并网点的频率和/或频率变化率引起的需要风电场调节的全场功率调节量。
作为示例，确定需要风电场调节的全场功率调节量的周期可为20ms。
在步骤S102，在处于一次调频模式的情况下，周期性地根据当前的全场功率调节量确定全场功率实际缺额。
作为示例，可先根据当前的全场功率调节量确定当前需要风电场调节到的全场功率目标值，然后将当前的全场功率目标值与当前的全场功率实际值之间的差值确定为全场功率实际缺额。
作为示例，可将本次电网频率扰动开始时的全场功率初始值与当前的全 场功率调节量之和，确定为当前需要风电场调节到的全场功率目标值。
作为示例，全场功率实际值可为风电场的并网点的实际功率或风电场的各台风力发电机组的实际功率的总和。
作为示例，确定全场功率实际缺额的周期可为20ms。
在步骤S103，根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量。
作为示例，所述预设时长的长度可小于5s，例如，所述预设时长可为1s或2s。
作为示例，每台机组在未来预设时长的变桨可调功率包括：该机组在未来预设时长的变桨可增功率和该机组在未来预设时长的变桨可降功率。
作为示例，针对每一台机组，如果其桨距角未达到其最小桨距角且功率未达到其限功率最大值，则可基于预设的该机组单位时间的变桨可增功率和预设时长的长度确定该机组在未来预设时长的变桨可增功率OneCycleUpPower；否则，该机组在未来预设时长的变桨可增功率可为0。机组的限功率最大值指：机组在当时的风况和运行状态下能达到的最大功率，因为可能处于限功率状态，所以实时功率可能小于这个最大值，这个最大值可能是额定功率，可能小于额定功率。
例如，桨距角未达到最小桨距角且功率未达到限功率最大值的机组在未来预设时长的变桨可增功率可为：预设的该机组单位时间的变桨可增功率(例如，预设1s的变桨可增功率)、预设时长以及第一转换偏差系数三者的乘积。
作为示例，针对每一台机组，如果其桨距角未达到其待机桨距角且功率未低于其限功率最小值，则可基于预设的该机组单位时间的变桨可降功率和预设时长的长度确定该机组在未来预设时长的变桨可降功率；否则，该机组在未来预设时长的变桨可降功率可为0。
例如，桨距角未达到待机桨距角且功率未低于限功率最小值的机组在未来预设时长的变桨可降功率为：预设的该机组单位时间的变桨可降功率、预设时长以及第二转换偏差系数三者的乘积。
作为示例，当需上调功率时，当机组桨距角还未达到最小桨距角PitPosMin，且机组的功率也未达到最大值LimPwrMaxDmd时，机组在未来预设时长的变桨可增功率OneCycleUpPower＝预设1s的调节能力ExecutionRate×单步长周期时长CloseLoopCycle×第一转换偏差系数，其中， 预设1s的调节能力ExecutionRate为预设1s的变桨可增功率，单步长周期时长CloseLoopCycle为预设时长，例如，第一转换偏差系数可为0.8。
作为示例，当需下调功率时，当机组桨距角还未达到待机桨距角StandbyPitPos，且机组的功率也未低于限功率最小值LimPwrMinDmd时，机组在未来预设时长的变桨可降功率OneCycleDownPower＝预设1s的调节能力ExecutionRate×单步长周期时长CloseLoopCycle×第二转换偏差系数，其中，预设1s的调节能力ExecutionRate为预设1s的变桨可降功率，单步长周期时长CloseLoopCycle为预设时长，例如，第二转换偏差系数可为0.8。
在一个实施例中，可在当前的全场功率实际缺额大于0的情况下，根据在未来预设时长的全场上调备用功率和当前的全场功率实际缺额，确定在未来预设时长的全场功率上调量，并基于在未来预设时长的全场功率上调量，确定各台机组的单机功率调节量。
作为示例，在未来预设时长的全场上调备用功率为各台桨距角未达到最小桨距角且功率未达到限功率最大值的机组在未来预设时长的变桨可增功率之和。例如，在未来预设时长的全场上调备用功率可为：
作为示例，可在在未来预设时长的全场上调备用功率大于全场功率实际缺额的情况下，将全场功率实际缺额确定为在未来预设时长的全场功率上调量；在在未来预设时长的全场上调备用功率小于全场功率实际缺额的情况下，将在未来预设时长的全场上调备用功率确定为在未来预设时长的全场功率上调量。
作为示例，针对每台桨距角未达到最小桨距角且功率未达到限功率最大值的机组，可基于该台机组的上调权重系数和在未来预设时长的全场功率上调量的乘积，确定该台机组的单机功率调节量。例如，针对每台桨距角未达到最小桨距角且功率未达到限功率最大值的机组，可将该台机组的上调权重系数和在未来预设时长的全场功率上调量的乘积与偏差修正值之和，作为该台机组的单机功率调节量。例如，每台机组的上调权重系数可为：该台机组的变桨上调功率能力与各台机组的变桨上调功率能力之和之间的比值，机组的变桨上调功率能力为机组的平均桨距角与最小桨距角之间的差值与机组的额定功率的乘积。应该理解，各台机组的变桨上调功率能力之和指的是各台桨距角未达到最小桨距角且功率未达到限功率最大值的机组的变桨上调功率 能力之和。
作为示例，机组的平均桨距角为：机组的所有叶片的桨距角的平均值。
作为示例，当需上调功率时，机组的变桨上调功率能力OneCapacity[i]＝(平均桨角βi–最小桨角βmin)×额定功率Pi rated；各台机组的变桨上调功率能力之和GTotalUPPitch为机组的上调权重系数Proportion[i]为作为示例，机组预下发的指令为DeltPTEMP[i]＝OneCommand[i]+Deviation[i]，OneCommand[i]为Proportion[i]×全场功率上调量，Deviation[i]为机组的偏差修正值。作为示例，机组预下发的速率为PwrRateSetTEMP[i]＝SlowPwrRateSet，也即，下发一次调频的标识。
在另一个实施例中，可在当前的全场功率实际缺额小于0的情况下，根据在未来预设时长的全场下调备用功率和当前的全场功率实际缺额，确定在未来预设时长的全场功率下调量，并基于在未来预设时长的全场功率下调量，确定各台机组的单机功率调节量。
作为示例，在未来预设时长的全场下调备用功率为各台桨距角未达到待机桨距角且功率未低于限功率最小值的机组在未来预设时长的变桨可降功率之和。例如，在未来预设时长的全场上调备用功率可为：
作为示例，可在在未来预设时长的全场下调备用功率小于全场功率实际缺额的情况下，将全场功率实际缺额确定为在未来预设时长的全场功率下调量；在在未来预设时长的全场下调备用功率大于全场功率实际缺额的情况下，将在未来预设时长的全场下调备用功率确定为在未来预设时长的全场功率下调量。
作为示例，针对每台桨距角未达到待机桨距角且功率未低于限功率最小值的机组，可基于该台机组的下调权重系数和在未来预设时长的全场功率下调量的乘积，确定该台机组的单机功率调节量。例如，针对每台桨距角未达到待机桨距角且功率未低于限功率最小值的机组，可将该台机组的下调权重系数和在未来预设时长的全场功率下调量的乘积与偏差修正值之和，作为该台机组的单机功率调节量。例如，每台机组的下调权重系数可为：该台机组的变桨下调功率能力与各台机组的变桨下调功率能力之和之间的比值，机组的变桨下调功率能力为机组的待机桨距角与平均桨距角之间的差值与机组的额定功率的乘积。应该理解，各台机组的变桨下调功率能力之和指的是各台 桨距角未达到待机桨距角且功率未低于限功率最小值的机组的变桨上调功率能力之和。
作为示例，当需下调功率时，机组的变桨下调功率能力OneCapacity[i]＝(待机桨距角βmax–平均桨角βi)×额定功率Pi rated；各台机组的变桨上调功率能力之和GTotalDownPitch为机组的下调权重系数Proportion[i]为作为示例，机组预下发的指令为DeltPTEMP[i]＝OneCommand[i]+Deviation[i]，OneCommand[i]为Proportion[i]×全场功率下调量，Deviation[i]为机组的偏差修正值。作为示例，机组预下发的速率为PwrRateSetTEMP[i]＝SlowPwrRateSet，也即，下发一次调频的标识。
作为示例，每台机组的偏差修正值可为：该台机组当前的功率实际值与本次电网频率扰动开始时该台机组的功率初始值P0之间的差值。
本公开考虑到相关技术中，某些风电场机组容量差异很大，采用已有的根据机组可调功率进行分配的算法，会导致小容量机组的调节深度过大，从而导致响应时间过长，不能满足电网要求。根据本公开的示例性实施例采用根据桨距角进行分配的算法，根据机组可调角度进行分配，调节深度不会因额定功率差异而定，而是根据机组的桨叶角度确定，这样每台机组调节量差异大了，但是相对调节深度不会扩大，能缩短正常的响应时间。根据本公开的示例性实施例，根据桨距角进行分配的算法降低了可调功率裕度偏差，提高了控制精度，具有国际国内普遍适用性。
此外，本公开考虑到相关技术中理论功率计算准确度不够高，且频率响应控制可调裕度是依据超短期风机预测理论功率进行计算的，因此控制过程中会有偏差，目前基于电网要求不断严苛的情况，提高响应精度是必做之事。根据本公开的示例性实施例，超短期风机预测理论功率只作为上送电网调控的参考，不作为具体控制的依据，从而能够提高控制响应精度。
此外，本公开考虑到相关技术中AGC设备，例如，能源管理平台(Energy Management Platform，EMP)低频备用功能投入后，EMP中上送给调度的可调功率与一次调频计算出来的可调功率相差甚远，导致一次调频响应不满足电网要求。因此，根据本公开的示例性实施例，当EMP与频率响应设备VMP计算的理论功率差距较大时，实际控制不受影响，依然能够保证响应到位，满足并网要求。
在步骤S104，分别向各台机组下发对应的单机功率调节量，以使各台机 组按照对应的单机功率调节量调整输出功率。
作为示例，在距最近一次下发单机功率调节量已达到预设时长的情况下，根据本公开的示例性实施例的风电场的频率响应控制方法还可包括：返回执行步骤S103。应该理解，每次返回执行步骤S103时，所根据的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率均为最新更新的。
具体地，作为示例，可在需要风电场调节的全场功率调节量未发生改变、且全场功率实际缺额超控制死区、且距最近一次下发单机功率调节量已达到预设时长的情况下，返回执行步骤S103。作为示例，可在需要风电场调节的全场功率调节量发生改变、且距最近一次下发单机功率调节量已达到特定时长(例如，200ms)的情况下，返回执行步骤S103。
根据本公开的示例性实施例，在并网点频率与功率双闭环的基础上，加上功率小步长多次迭代调节，功率小步长多次迭代调节即将计划调节量按照一定的步长进行拆分，按照步长周期性的多次迭代的方式将单机调节量下发给机组的控制方式。从而实现多层级联控制，其中并网点频率、频率变化率闭环为最外环控制(也即第一环控制)，是直接导致目标值变化的量；全场并网点功率或者机组有功合计闭环为中间环控制(也即第二环控制)，是跟随第一环目标值随时调节的量，当第一环目标值不变时，第二环周期性检测是否当前功率满足第一环目标值；小步长多次迭代控制为最内环控制(也即第三环控制)，属于动作最频繁的一环，在第二环确定全场总功率实际缺额后，在第三环按照步长(也即，上述所提到的预设时长)进行切分，然后按照每一个步长控制量进行控制。单个步长控制周期结束后，再回到第二环，这样循环往复的进行，直到第二环满足控制死区范围，最后等第一环进入频率和频率变化率死区后，彻底结束控制。
图5示出根据本公开的示例性实施例的一次调频模式的示例。也即，第二环到第三环的控制流程。“小步长控制计算”的核心思想为：具备桨距角调节能力的机组，按照预设计的调节速度，计算单周期可调节的最大功率，再按照实际需求按单周期可调节最大功率进行迭代切分执行。“桨角比例算法”的核心思想为：机组限功率时一定会变桨，桨距角的比例与限功率深度近似成比例，自由发电时不变桨。因此依据正向比例关系，可以算出每台风机在当前桨距角情况下调节功率的权重比例，再依据权重进行功率调节，来达到分配控制的目的。
图6示出根据本公开的另一示例性实施例的风电场的频率响应控制方法的流程图。
如图6所示，在步骤S201，检测并网点的频率和频率变化率。
在步骤S202，周期性地确定由并网点的频率和/或频率变化率引起的需要风电场调节的全场功率调节量。
在步骤S203，周期性地确定风电场所需进入的有功调节模式。作为示例，可根据并网点的频率和频率变化率，确定风电场所需进入的有功调节模式。
作为示例，确定风电场所需进入的有功调节模式的周期可为20ms。
作为示例，可根据并网点的频率和频率变化率，使用适当的判断策略，确定风电场所需进入的有功调节模式是一次调频模式、惯量响应模式、快速降功率模式之中的哪一者。
在步骤S204，响应于所需进入的有功调节模式为一次调频模式，进入一次调频模式。
在步骤S205，响应于所需进入的有功调节模式为惯量响应模式，进入惯量响应模式。
在步骤S206，响应于所需进入的有功调节模式为快速降功率模式，进入快速降功率模式。应该理解，风电场同一时间仅能处于一种有功调节模式。
在步骤S207，在处于一次调频模式的情况下，周期性地根据当前的全场功率调节量确定全场功率实际缺额。
在步骤S208，根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量。
在步骤S209，分别向各台机组下发对应的单机功率调节量，以使各台机组按照对应的单机功率调节量调整输出功率。在距最近一次下发单机功率调节量已达到预设时长的情况下，返回执行步骤S208。
根据本公开的示例性实施例，一次调频按照三环级联控制方式实现，惯量响应和快速降功率按照并网点频率闭环进行控制。
应该理解，进入惯量响应模式后，可通过适当的方式确定各台机组的单机功率调节量，并分别向各台机组下发对应的单机功率调节量，以使各台机组按照对应的单机功率调节量调整输出功率，本公开在此不再赘述。
应该理解，进入快速降功率模式后，可通过适当的方式确定各台机组的单机功率调节量，并分别向各台机组下发对应的单机功率调节量，以使各台 机组按照对应的单机功率调节量调整输出功率，机组在快速降功率模式下可通过制动电阻消耗可降低的有功功率量，本公开在此不再赘述。
此外，作为示例，在处于惯量响应模式的情况下，根据本公开的另一示例性实施例的风电场的频率响应控制方法还可包括：在电网频率变化率超频率变化率死区且电网频率未超频率死区的情况下，如果电网频率变化率在惯量响应可持续时间未达到时就回到频率变化率死区，则分别向各台机组下发预设的单机功率调节量；在电网频率变化率超频率变化率死区且电网频率未超频率死区的情况下，如果电网频率变化率在惯量响应可持续时间达到时未回到频率变化率死区，则分别向各台机组下发预设的单机功率调节量。
本公开针对惯量响应做了相应的调整，每次惯量响应，无论后面有没有衔接一次调频，都是以小deltP(即，预设的单机功率调节量)，和一次调频的慢速速率进行过渡，然后结束控制，结束控制，即执行图8中的“退出过程分配”。小deltP即频率控制后，在回归到调频前的模式的过程中有一小段非常接近目标功率的指令，就是这个小deltP，这个小deltP控制时间到了之后，就直接给目标值和使能标志位清0以结束控制。
如图7所示，1代表一次调频增功率，-1代表一次调频降功率，数字代表工况，惯量响应因控制惯量时间到了，或者扰动结束了，强制回归到一次调频的方式结束控制。具体地，可分为以下几种情况：1、频率变化率超死区，频率未超死区：频率变化率在惯量响应可持续时间未达到时，就回到死区，则跟小deltP结束；2、频率变化率超死区，频率未超死区：频率变化率超出惯量响应可持续时间未回死区，则按照持续时间到了，就跟小deltP结束；3、频率变化率超死区，频率也超死区：频率变化率在持续时间未达到时，就回到死区，则跟一次调频指令，然后小deltP结束；4、频率变化率超死区，频率也超死区：频率变化率超出持续时间未回死区，则按照持续时间到了，跟一次调频指令，然后小deltP结束。
此外，作为另一示例，在处于快速降功率模式的情况下，根据本公开的另一示例性实施例的风电场的频率响应控制方法还可包括：在恢复阶段，按照快速降功率恢复方式控制风电场的具备快速降功率能力的机组，并按照一次调频恢复方式控制风电场的不具备快速降功率能力的机组。
快速降功率工况，与之匹配的响应速率为快速FastPwrRateSet，恢复阶段，由于采用闭环控制，以当前功率为基准，需要上调的实际缺额根据当前 实际情况确定，当恢复时实际缺额DeltPReal为正数，则会进入正常的上调功率分配，上调时如果触发的是快速降功率模式，则判断机组状态是不是快速运行状态PROT_iAllowPFC＝2，如果是则可启动快速恢复，否则按照正常的慢速率恢复。如果是快速触发快速降功率，快速恢复至死区内，则速率为快速FastPwrRateSet，如果快速触发快速降功率，恢复过程至一次调频工况过程，则恢复速率为一次调频慢速率SlowPwrRateSet。如果快速降功率不参考机组允许状态PROT_iAllowPFC＝2，则可能降功率时，机组按照慢速率运行，恢复的时候，启动快速率恢复，则显得很突兀；如果快速触发快速降功率，恢复过程至一次调频过程，则恢复速率为一次调频慢速率SlowPwrRateSet。具体说来，快速降功率模式启动后，分配时某些机组不具备这个能力，针对这些机组按照慢速一次调频的方式进行控制，具备能力的机组按照快速降功率的方式进行控制，但结束控制时，如果所有机组都按照快速率结束，就会显得很突兀。因此，这时增加了退出时的机组状态判断，如果当时机组有快速调节的能力，则按照快速率结束，如果机组没有快速调节的能力，则按照慢速率结束。此外，当从快速降功率模式切换到了一次调频模式，那么这时，所有机组都会按照慢速率结束控制。
根据本公开的示例性实施例，考虑到一次调频小步快调涉及到惯量响应与快速降功率控制，小步快调的控制方式引进之后，对惯量响应和快速降功率也做了相应调整。
图8示出根据本公开的另一示例性实施例的风电场的频率响应控制方法的流程图。这里，CP方式指的是利用理论功率表基于机组当前的桨距角和风速确定机组的理论功率。综合指令即需要风电场调节的全场功率调节量。
根据本公开的示例性实施例，能够解决风电场频率控制响应时间长的问题；能够提高频率控制整场精度；能够减弱频率响应控制对理论功率的依赖；能够避免不同控制设备之间算法的差异导致频率控制不合格的问题。
图9示出根据本公开的示例性实施例的风电场的频率响应控制装置的结构框图。
如图9所示，根据本公开的示例性实施例的风电场的频率响应控制装置包括：全场功率调节量确定单元101、全场功率实际缺额确定单元102、单机功率调节量确定单元103、下发单元104。
具体说来，全场功率调节量确定单元101被配置为周期性地确定由并网 点的频率和/或频率变化率引起的需要风电场调节的全场功率调节量。
全场功率实际缺额确定单元102被配置为在处于一次调频模式的情况下，周期性地根据当前的全场功率调节量确定全场功率实际缺额。
单机功率调节量确定单元103被配置为根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量。
下发单元104被配置为分别向各台机组下发对应的单机功率调节量，以使各台机组按照对应的单机功率调节量调整输出功率。
作为示例，单机功率调节量确定单元103还可被配置为：在距最近一次下发单机功率调节量已达到预设时长的情况下，根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量。
作为示例，所述频率响应控制装置还可包括：有功调节模式确定单元(未示出)，有功调节模式确定单元被配置为周期性地根据并网点的频率和频率变化率，确定风电场所需进入的有功调节模式；响应于所需进入的有功调节模式为一次调频模式，进入一次调频模式；响应于所需进入的有功调节模式为惯量响应模式，进入惯量响应模式；响应于所需进入的有功调节模式为快速降功率模式，进入快速降功率模式，其中，风电场同一时间仅能处于一种有功调节模式。
作为示例，机组在未来预设时长的变桨可调功率可包括：机组在未来预设时长的变桨可增功率和机组在未来预设时长的变桨可降功率；桨距角未达到最小桨距角且功率未达到限功率最大值的机组在未来预设时长的变桨可增功率为：预设的该机组单位时间的变桨可增功率、预设时长以及第一转换偏差系数三者的乘积；桨距角未达到待机桨距角且功率未低于限功率最小值的机组在未来预设时长的变桨可降功率为：预设的该机组单位时间的变桨可降功率、预设时长以及第二转换偏差系数三者的乘积。
作为示例，单机功率调节量确定单元103可被配置为：在当前的全场功率实际缺额大于0的情况下，根据在未来预设时长的全场上调备用功率和当前的全场功率实际缺额，确定在未来预设时长的全场功率上调量，并基于在未来预设时长的全场功率上调量，确定各台机组的单机功率调节量；在当前的全场功率实际缺额小于0的情况下，根据在未来预设时长的全场下调备用 功率和当前的全场功率实际缺额，确定在未来预设时长的全场功率下调量，并基于在未来预设时长的全场功率下调量，确定各台机组的单机功率调节量，其中，在未来预设时长的全场上调备用功率为各台机组在未来预设时长的变桨可增功率之和，在未来预设时长的全场下调备用功率为各台机组在未来预设时长的变桨可降功率之和。
作为示例，单机功率调节量确定单元103可被配置为：在在未来预设时长的全场上调备用功率大于全场功率实际缺额的情况下，将全场功率实际缺额确定为在未来预设时长的全场功率上调量；在在未来预设时长的全场上调备用功率小于全场功率实际缺额的情况下，将在未来预设时长的全场上调备用功率确定为在未来预设时长的全场功率上调量。
作为示例，单机功率调节量确定单元103可被配置为：在在未来预设时长的全场下调备用功率小于全场功率实际缺额的情况下，将全场功率实际缺额确定为在未来预设时长的全场功率下调量；在在未来预设时长的全场下调备用功率大于全场功率实际缺额的情况下，将在未来预设时长的全场下调备用功率确定为在未来预设时长的全场功率下调量。
作为示例，单机功率调节量确定单元103可被配置为：针对每台桨距角未达到最小桨距角且功率未达到限功率最大值的机组，将该台机组的上调权重系数和在未来预设时长的全场功率上调量的乘积与偏差修正值之和，作为该台机组的单机功率调节量，其中，每台机组的上调权重系数为：该台机组的变桨上调功率能力与各台机组的变桨上调功率能力之和之间的比值，机组的变桨上调功率能力为机组的平均桨距角与最小桨距角之间的差值与机组的额定功率的乘积。
作为示例，单机功率调节量确定单元103可被配置为：针对每台桨距角未达到待机桨距角且功率未低于限功率最小值的机组，将该台机组的下调权重系数和在未来预设时长的全场功率下调量的乘积与偏差修正值之和，作为该台机组的单机功率调节量，其中，每台机组的下调权重系数为：该台机组的变桨下调功率能力与各台机组的变桨下调功率能力之和之间的比值，机组的变桨下调功率能力为机组的待机桨距角与平均桨距角之间的差值与机组的额定功率的乘积。
作为示例，每台机组的偏差修正值可为：该台机组当前的功率实际值与本次电网频率扰动开始时该台机组的功率初始值之间的差值。
作为示例，所述频率响应控制装置还可包括：惯量响应控制单元(未示出)，惯量响应控制单元被配置为在处于惯量响应模式的情况下，在电网频率变化率超频率变化率死区且电网频率未超频率死区的情况下，如果电网频率变化率在惯量响应可持续时间未达到时就回到频率变化率死区，则分别向各台机组下发预设的单机功率调节量；在电网频率变化率超频率变化率死区且电网频率未超频率死区的情况下，如果电网频率变化率在惯量响应可持续时间达到时未回到频率变化率死区，则分别向各台机组下发预设的单机功率调节量。
作为示例，所述频率响应控制装置还可包括：快速降功率控制单元(未示出)，快速降功率控制单元被配置为在处于快速降功率模式的情况下，在恢复阶段，按照快速降功率恢复方式控制风电场的具备快速降功率能力的机组，并按照一次调频恢复方式控制风电场的不具备快速降功率能力的机组。
作为示例，所述频率响应控制装置可设置在风电场的控制器中。
应该理解，根据本公开示例性实施例的风电场的频率响应控制装置所执行的具体处理已经参照图1至图8进行了详细描述，这里将不再赘述相关细节。
应该理解，根据本公开示例性实施例的风电场的频率响应控制装置中的各个单元可被实现硬件组件和/或软件组件。本领域技术人员根据限定的各个单元所执行的处理，可以例如使用现场可编程门阵列(FPGA)或专用集成电路(ASIC)来实现各个单元。
本公开的示例性实施例提供一种存储有计算机程序的计算机可读存储介质，当所述计算机程序被处理器执行时，促使所述处理器执行如上述示例性实施例所述的风电场的频率响应控制方法。该计算机可读存储介质是可存储由计算机系统读出的数据的任意数据存储装置。计算机可读存储介质的示例包括：只读存储器、随机存取存储器、只读光盘、磁带、软盘、光数据存储装置和载波(诸如经有线或无线传输路径通过互联网的数据传输)。
根据本公开的示例性实施例的风电场的频率响应控制装置包括：处理器(未示出)和存储器(未示出)，其中，存储器存储有计算机程序，当所述计算机程序被处理器执行时，促使所述处理器执行如上述示例性实施例所述的风电场的频率响应控制方法。
作为示例，所述频率响应控制装置可设置在风电场的控制器中。
虽然已表示和描述了本公开的一些示例性实施例，但本领域技术人员应该理解，在不脱离由权利要求及其等同物限定其范围的本公开的原理和精神的情况下，可以对这些实施例进行修改。

Claims (15)

  1. 一种风电场的频率响应控制方法，其中，包括：
    周期性地确定由并网点的频率和/或频率变化率引起的需要风电场调节的全场功率调节量；
    在处于一次调频模式的情况下，周期性地根据当前的全场功率调节量确定全场功率实际缺额；
    根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量；
    分别向各台机组下发对应的单机功率调节量，以使各台机组按照对应的单机功率调节量调整输出功率。
  2. 根据权利要求1所述的频率响应控制方法，其中，在距最近一次下发单机功率调节量已达到预设时长的情况下，所述方法还包括：返回执行根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量的步骤。
  3. 根据权利要求1所述的频率响应控制方法，其中，所述频率响应控制方法还包括：
    周期性地根据并网点的频率和频率变化率，确定风电场所需进入的有功调节模式；
    响应于所需进入的有功调节模式为一次调频模式，进入一次调频模式；
    响应于所需进入的有功调节模式为惯量响应模式，进入惯量响应模式；
    响应于所需进入的有功调节模式为快速降功率模式，进入快速降功率模式，
    其中，风电场同一时间仅能处于一种有功调节模式。
  4. 根据权利要求1或2所述的频率响应控制方法，其中，机组在未来预设时长的变桨可调功率包括：机组在未来预设时长的变桨可增功率和机组在未来预设时长的变桨可降功率；
    桨距角未达到最小桨距角且功率未达到限功率最大值的机组在未来预设时长的变桨可增功率为：预设的该机组单位时间的变桨可增功率、预设时长以及第一转换偏差系数三者的乘积；
    桨距角未达到待机桨距角且功率未低于限功率最小值的机组在未来预设 时长的变桨可降功率为：预设的该机组单位时间的变桨可降功率、预设时长以及第二转换偏差系数三者的乘积。
  5. 根据权利要求1或2所述的频率响应控制方法，其中，根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量的步骤包括：
    在当前的全场功率实际缺额大于0的情况下，根据在未来预设时长的全场上调备用功率和当前的全场功率实际缺额，确定在未来预设时长的全场功率上调量，并基于在未来预设时长的全场功率上调量，确定各台机组的单机功率调节量；
    在当前的全场功率实际缺额小于0的情况下，根据在未来预设时长的全场下调备用功率和当前的全场功率实际缺额，确定在未来预设时长的全场功率下调量，并基于在未来预设时长的全场功率下调量，确定各台机组的单机功率调节量，
    其中，在未来预设时长的全场上调备用功率为各台机组在未来预设时长的变桨可增功率之和，在未来预设时长的全场下调备用功率为各台机组在未来预设时长的变桨可降功率之和。
  6. 根据权利要求5所述的频率响应控制方法，其中，根据在未来预设时长的全场上调备用功率和当前的全场功率实际缺额，确定在未来预设时长的全场功率上调量的步骤包括：
    在在未来预设时长的全场上调备用功率大于全场功率实际缺额的情况下，将全场功率实际缺额确定为在未来预设时长的全场功率上调量；
    在在未来预设时长的全场上调备用功率小于全场功率实际缺额的情况下，将在未来预设时长的全场上调备用功率确定为在未来预设时长的全场功率上调量。
  7. 根据权利要求5所述的频率响应控制方法，其中，根据在未来预设时长的全场下调备用功率和当前的全场功率实际缺额，确定在未来预设时长的全场功率下调量的步骤包括：
    在在未来预设时长的全场下调备用功率小于全场功率实际缺额的情况下，将全场功率实际缺额确定为在未来预设时长的全场功率下调量；
    在在未来预设时长的全场下调备用功率大于全场功率实际缺额的情况下，将在未来预设时长的全场下调备用功率确定为在未来预设时长的全场功率下 调量。
  8. 根据权利要求5所述的频率响应控制方法，其中，基于在未来预设时长的全场功率上调量，确定各台机组的单机功率调节量的步骤包括：
    针对每台桨距角未达到最小桨距角且功率未达到限功率最大值的机组，将该台机组的上调权重系数和在未来预设时长的全场功率上调量的乘积与偏差修正值之和，作为该台机组的单机功率调节量，
    其中，每台机组的上调权重系数为：该台机组的变桨上调功率能力与各台机组的变桨上调功率能力之和之间的比值，机组的变桨上调功率能力为机组的平均桨距角与最小桨距角之间的差值与机组的额定功率的乘积。
  9. 根据权利要求5所述的频率响应控制方法，其中，基于在未来预设时长的全场功率下调量，确定各台机组的单机功率调节量的步骤包括：
    针对每台桨距角未达到待机桨距角且功率未低于限功率最小值的机组，将该台机组的下调权重系数和在未来预设时长的全场功率下调量的乘积与偏差修正值之和，作为该台机组的单机功率调节量，
    其中，每台机组的下调权重系数为：该台机组的变桨下调功率能力与各台机组的变桨下调功率能力之和之间的比值，机组的变桨下调功率能力为机组的待机桨距角与平均桨距角之间的差值与机组的额定功率的乘积。
  10. 根据权利要求8或9所述的频率响应控制方法，其中，每台机组的偏差修正值为：
    该台机组当前的功率实际值与本次电网频率扰动开始时该台机组的功率初始值之间的差值。
  11. 根据权利要求3所述的频率响应控制方法，其中，在处于惯量响应模式的情况下，所述频率响应控制方法还包括：
    在电网频率变化率超频率变化率死区且电网频率未超频率死区的情况下，如果电网频率变化率在惯量响应可持续时间未达到时就回到频率变化率死区，则分别向各台机组下发预设的单机功率调节量；
    在电网频率变化率超频率变化率死区且电网频率未超频率死区的情况下，如果电网频率变化率在惯量响应可持续时间达到时未回到频率变化率死区，则分别向各台机组下发预设的单机功率调节量。
  12. 根据权利要求3所述的频率响应控制方法，其中，在处于快速降功率模式的情况下，所述频率响应控制方法还包括：
    在恢复阶段，按照快速降功率恢复方式控制风电场的具备快速降功率能力的机组，并按照一次调频恢复方式控制风电场的不具备快速降功率能力的机组。
  13. 一种风电场的频率响应控制装置，其中，包括：
    全场功率调节量确定单元，被配置为周期性地确定由并网点的频率和/或频率变化率引起的需要风电场调节的全场功率调节量；
    全场功率实际缺额确定单元，被配置为在处于一次调频模式的情况下，周期性地根据当前的全场功率调节量确定全场功率实际缺额；
    单机功率调节量确定单元，被配置为根据当前的全场功率实际缺额和风电场的各台机组在未来预设时长的变桨可调功率，确定各台机组的单机功率调节量；
    下发单元，被配置为分别向各台机组下发对应的单机功率调节量，以使各台机组按照对应的单机功率调节量调整输出功率。
  14. 一种存储有计算机程序的计算机可读存储介质，其中，当所述计算机程序被处理器执行时，促使所述处理器执行如权利要求1至12中的任意一项所述的风电场的频率响应控制方法。
  15. 一种风电场的频率响应控制装置，其中，所述频率响应控制装置包括：
    处理器；
    存储器，存储有计算机程序，当所述计算机程序被处理器执行时，促使所述处理器执行如权利要求1至12中的任意一项所述的风电场的频率响应控制方法。
PCT/CN2023/108874 2022-10-20 2023-07-24 风电场的频率响应控制方法及装置 WO2024082746A1 (zh)

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