CN117375115A

CN117375115A - Active power regulation method and device for wind power plant

Info

Publication number: CN117375115A
Application number: CN202210771456.2A
Authority: CN
Inventors: 左美灵
Original assignee: Beijing Goldwind Science and Creation Windpower Equipment Co Ltd
Current assignee: Beijing Goldwind Science and Creation Windpower Equipment Co Ltd
Priority date: 2022-06-30
Filing date: 2022-06-30
Publication date: 2024-01-09

Abstract

An active power regulation method and device for a wind farm are provided. The active power adjustment method comprises the following steps: starting from reaching a primary frequency modulation triggering condition, determining a full-field active adjustment quantity required to be adjusted by the wind power plant every a first preset time length, and determining whether the preset condition is met or not based on the full-field active adjustment quantity; when the preset condition is met, determining full-field adjustable standby power; based on the full-field active adjustment quantity and the full-field adjustable standby power, determining a single-machine active adjustment quantity corresponding to each wind generating set of the wind power plant; and respectively issuing corresponding single machine active adjustment quantity to each wind generating set so as to control each wind generating set to perform active adjustment.

Description

Active power regulation method and device for wind power plant

Technical Field

The present disclosure relates generally to the field of power technology, and more particularly, to a method and apparatus for active regulation of a wind farm.

Background

With the continuous expansion of the wind power access scale of the power system, the scheduling problem and the operation pressure of the power system are increasingly remarkable, and a system scheduling department has to schedule a traditional unit to hold more frequency modulation capacity so as to ensure the smooth absorption of wind power. On the one hand, the operation pressure of the traditional unit and the complexity of system scheduling operation are increased, and on the other hand, the economic and environmental protection benefits brought by wind power grid connection are reduced or offset. With the improvement of the control technology of the wind generating set, the wind generating set can participate in system frequency modulation to a certain extent.

Primary frequency modulation (Primary Frequency Control, PFR) refers to a control function in which a wind farm adjusts active force to reduce frequency deviation of a power system (e.g., a grid) by controlling the system's automatic reaction when the frequency of the power system deviates from a target frequency. The automatic power generation control (Automatic Generation Control, AGC) means that the wind power plant is enabled to track the instruction issued by the power dispatching transaction mechanism within the specified output adjustment range through an automatic control program, and the power generation output is adjusted in real time according to a certain adjustment rate so as to meet the service of the frequency and power control requirements of the power system.

The wind power plant participates in system frequency modulation, provides rapid and accurate active power support, meets the safety operation requirement of a power grid, and has important significance in improving the permeability of a new energy station and ensuring the stable operation of a power system. Therefore, how to adjust the active power of the wind farm to effectively meet the system frequency modulation requirements is important.

Disclosure of Invention

An exemplary embodiment of the present disclosure provides an active power adjustment method and apparatus for a wind farm, which can effectively adjust active power of the wind farm for primary frequency modulation scenarios.

According to a first aspect of embodiments of the present disclosure, there is provided a method for active regulation of a wind farm, comprising: starting from reaching a primary frequency modulation triggering condition, determining a full-field active adjustment quantity required to be adjusted by the wind power plant every a first preset time length, and determining whether the preset condition is met or not based on the full-field active adjustment quantity; when the preset condition is met, determining full-field adjustable standby power; based on the full-field active adjustment quantity and the full-field adjustable standby power, determining a single-machine active adjustment quantity corresponding to each wind generating set of the wind power plant; and respectively issuing corresponding single machine active adjustment quantity to each wind generating set so as to control each wind generating set to perform active adjustment.

Optionally, in the case that automatic power generation control AGC is required for the wind farm at present, the full-farm active adjustment amount is: the sum of the AGC full field active adjustment amount for implementing AGC and the primary frequency modulation full field active adjustment amount for implementing primary frequency modulation.

Optionally, the preset condition includes: the first preset condition or the second preset condition, wherein the first preset condition is as follows: the determined full-field active adjustment quantity is different from the last determined full-field active adjustment quantity, and the active adjustment quantity of the single machine issued last time reaches a second preset duration; the second preset condition is as follows: the determined full-field active adjustment quantity is the same as the last determined full-field active adjustment quantity, the active adjustment quantity of the single machine issued last time reaches a third preset duration, and the difference between the full-field actual power and the full-field power target value which is required to be reached by the active adjustment quantity of the single machine issued last time exceeds a full-field power control precision dead zone.

Optionally, the step of determining the single-machine active adjustment amount corresponding to each wind generating set of the wind farm based on the full-field active adjustment amount and the full-field adjustable standby power includes: based on the full-field actual power and the primary frequency modulation full-field active initial value, correcting the full-field active adjustment quantity to obtain a corrected full-field active adjustment quantity based on the full-field actual power; determining a single-machine active adjustment quantity of each wind generating set based on the corrected full-field active adjustment quantity and full-field adjustable standby power; and correcting the single-machine active adjustment quantity of each wind generating set based on the actual power and the primary frequency modulation active initial value of the wind generating set to obtain the corrected single-machine active adjustment quantity based on the primary frequency modulation active initial value.

Optionally, the step of obtaining the corrected full-field active adjustment amount based on the full-field actual power includes: and determining a sum value of the primary frequency modulation full-field active initial value and the full-field active adjustment quantity, and determining a difference value between the sum value and the full-field actual power as a corrected full-field active adjustment quantity.

Optionally, the step of obtaining the corrected single machine active adjustment amount based on the primary frequency modulation active initial value includes: and aiming at each wind generating set, superposing the difference between the actual power of the wind generating set and the primary frequency modulation active initial value on the basis of the single-machine active adjustment quantity of the wind generating set to obtain the corrected single-machine active adjustment quantity based on the primary frequency modulation active initial value.

Optionally, the full farm actual power is the sum of the actual power of the grid connection points or the actual power of each wind turbine generator set of the wind farm.

Optionally, the AGC full field active adjustment is determined by: the AGC full field active adjustment is determined as: the difference between the current AGC execution plan value and the full-field active initial value of primary frequency modulation, or the difference between the current AGC execution plan value and the AGC execution plan value when the primary frequency modulation triggering condition is reached;

Or determining the number of the remaining control sub-periods for the AGC scheduling plan value issued last time according to the time of the issuing period from the next AGC scheduling plan value, and determining the ratio of the remaining part to be executed of the AGC scheduling plan value issued last time to the number of the remaining control sub-periods as the adjustment quantity of a single remaining control sub-period; and when the AGC compensation value is in the ith residual control subcycle, determining the sum of the AGC compensation value and the adjustment quantity of the i single residual control subcycle as the AGC full-field active adjustment quantity, wherein the AGC compensation value is the difference value between the last AGC scheduling plan value of the AGC scheduling plan value issued last time and the active initial value of the primary frequency modulation full-field, the AGC execution plan value is the smaller value of the AGC scheduling plan value and the active scheduling value of the wind power plant, and the AGC scheduling plan value is the active scheduling plan value of the network side.

Optionally, in the case that the adjustment amount of the single remaining control sub-period is determined for the first time after the primary frequency modulation triggering condition is reached, the remaining to-be-executed portion of the AGC scheduling plan value issued last time is: the difference between the latest issued AGC scheduling plan value and the primary frequency modulation full-field active initial value; in the case that the adjustment amount of a single remaining control sub-period is not determined for the first time after the primary frequency modulation triggering condition is reached, the remaining to-be-executed part of the AGC scheduling plan value issued last time is: the difference between the last AGC scheduling plan value issued and the last AGC scheduling plan value.

Optionally, the full-field adjustable standby power comprises: full-field up-regulation of standby power and full-field down-regulation of standby power; wherein the step of determining the full field adjustable standby power comprises: the method comprises the steps of adjusting reserve power in a variable pitch mode, adjusting reserve power in an inertia mode and adjusting reserve power in a rotor kinetic energy mode of each wind generating set of a wind power plant, and determining full-field up-adjustment reserve power; the method comprises the steps of adjusting standby power in a variable pitch mode, adjusting standby power in an inertia mode and adjusting standby power in a braking resistance mode of each wind generating set based on a wind power plant, and determining full-field down-adjustment standby power, wherein the variable pitch mode of the wind generating set with theoretical power smaller than actual power is as follows: the wind generating set is used for up-regulating the sum of standby power and up-regulating margin based on a pitching mode of actual power, wherein the up-regulating margin is larger than 0.

According to a second aspect of embodiments of the present disclosure, there is provided an active power conditioning device for a wind farm, comprising: the full-field active adjustment quantity determining unit is configured to determine full-field active adjustment quantity required to be adjusted by the wind power plant every a first preset time period from the time when the primary frequency modulation triggering condition is reached; a judging unit configured to determine whether a preset condition is satisfied based on the full-field active adjustment amount; a standby power determining unit configured to determine full-field adjustable standby power when the preset condition is satisfied; a single-machine active adjustment amount determining unit configured to determine a single-machine active adjustment amount corresponding to each wind power generator set of the wind power plant based on the full-field active adjustment amount and the full-field adjustable standby power; and the issuing unit is configured to issue corresponding single-machine active adjustment amounts to each wind generating set respectively so as to control each wind generating set to perform active adjustment.

Alternatively, the stand-alone active adjustment amount determination unit is configured to: based on the full-field actual power and the primary frequency modulation full-field active initial value, correcting the full-field active adjustment quantity to obtain a corrected full-field active adjustment quantity based on the full-field actual power; determining a single-machine active adjustment quantity of each wind generating set based on the corrected full-field active adjustment quantity and full-field adjustable standby power; and correcting the single-machine active adjustment quantity of each wind generating set based on the actual power and the primary frequency modulation active initial value of the wind generating set to obtain the corrected single-machine active adjustment quantity based on the primary frequency modulation active initial value.

Alternatively, the stand-alone active adjustment amount determination unit is configured to: and determining a sum value of the primary frequency modulation full-field active initial value and the full-field active adjustment quantity, and determining a difference value between the sum value and the full-field actual power as a corrected full-field active adjustment quantity.

Alternatively, the stand-alone active adjustment amount determination unit is configured to: and aiming at each wind generating set, superposing the difference between the actual power of the wind generating set and the primary frequency modulation active initial value on the basis of the single-machine active adjustment quantity of the wind generating set to obtain the corrected single-machine active adjustment quantity based on the primary frequency modulation active initial value.

Optionally, the full-field adjustable standby power comprises: full-field up-regulation of standby power and full-field down-regulation of standby power; wherein the standby power determination unit is configured to: the method comprises the steps of adjusting reserve power in a variable pitch mode, adjusting reserve power in an inertia mode and adjusting reserve power in a rotor kinetic energy mode of each wind generating set of a wind power plant, and determining full-field up-adjustment reserve power; the method comprises the steps of adjusting standby power in a variable pitch mode, adjusting standby power in an inertia mode and adjusting standby power in a braking resistance mode of each wind generating set based on a wind power plant, and determining full-field down-adjustment standby power, wherein the variable pitch mode of the wind generating set with theoretical power smaller than actual power is as follows: the wind generating set is used for up-regulating the sum of standby power and up-regulating margin based on a pitching mode of actual power, wherein the up-regulating margin is larger than 0.

Optionally, the active power adjustment device is provided in a controller of the wind farm.

According to a third aspect of embodiments of the present disclosure, there is provided a computer readable storage medium storing a computer program which, when executed by a processor, causes the processor to perform the active regulation method of a wind farm as described above.

According to a fourth aspect of embodiments of the present disclosure, there is provided an active power conditioning device for a wind farm, the active power conditioning device comprising: a processor; a memory storing a computer program which, when executed by a processor, causes the processor to perform the active regulation method of a wind farm as described above.

According to the method and the device for adjusting the active power of the wind power plant, which are disclosed by the embodiment of the invention, the active power of the wind power plant can be effectively adjusted aiming at primary frequency modulation scenes. In addition, especially for long-time primary frequency modulation application scenes, the control precision can be greatly improved, and the response time is shortened.

Additional aspects and/or advantages of the present general inventive concept will be set forth in part in the description which follows and, in part, will be obvious from the description, or may be learned by practice of the general inventive concept.

Drawings

The foregoing and other objects and features of exemplary embodiments of the present disclosure will become more apparent from the following description taken in conjunction with the accompanying drawings which illustrate the embodiments by way of example, in which:

fig. 1 illustrates a topology of a wind farm according to an exemplary embodiment of the present disclosure;

FIG. 2 illustrates an example of primary frequency droop control according to an example embodiment of the present disclosure;

FIG. 3 illustrates a flowchart of a method of active modulation of a wind farm according to an exemplary embodiment of the present disclosure;

FIG. 4 illustrates a flowchart of a method of determining a corresponding stand-alone active adjustment for each wind turbine of a wind farm, according to an exemplary embodiment of the present disclosure;

fig. 5 shows a block diagram of a structure of an active regulation device of a wind farm according to an exemplary embodiment of the present disclosure.

Detailed Description

Reference will now be made in detail to embodiments of the present disclosure, examples of which are illustrated in the accompanying drawings, wherein like reference numerals refer to the like elements throughout. The embodiments will be described below in order to explain the present disclosure by referring to the figures.

Fig. 1 illustrates a topology of a wind farm according to an exemplary embodiment of the present disclosure.

Referring to FIG. 1, a wind farm level controller (e.g., the farm control system of FIG. 1) as a top level control device may monitor grid-tie point data and centrally control all wind turbine generators (also referred to simply as fans, wind turbines).

As an example, the device for implementing the primary frequency modulation function (i.e., the primary frequency modulation control device) may control the grid-tie active power according to the detected grid-tie frequency to satisfy that the grid-tie frequency is within the dead zone range. The primary frequency modulation control device controls the fan in a power section from the power control lower limit of the fan to below the rated power, can not trigger primary frequency modulation control when the power is smaller than the power control lower limit, and can not stop the machine due to frequency modulation power limit in the process after triggering control. As an example, the primary frequency modulation control device may be a reactive management platform (Voltage/Var Management Platform, VMP).

As an example, the main function of the device for implementing AGC (i.e. AGC device) is to control the active power of the wind farm, receive the scheduling values on the grid side, and control the active power of the grid-connected point according to the scheduling values to meet the requirements of the scheduling values. The AGC device can control the fan in the full power section according to the scheduling plan value, including the actions of starting up the power, stopping the power and the like. As an example, the AGC device may be an energy management platform (Energy Management Platform, EMP).

In the prior art, the AGC device and the primary frequency modulation control device are operated in parallel, both devices need to control the fan, and the fan can only be controlled by one device at the same time, so that under different working conditions, the two devices need to be switched to control the fan.

As an example, under the condition of high-frequency disturbance of a wind farm power grid, the primary frequency modulation action quantity can be not adjusted downwards after reaching 10% of rated output force, and under the condition of low-frequency disturbance of the power grid, the primary frequency modulation action quantity can not be adjusted upwards (10% and 6% are recommended set values) after reaching 6% of rated output force. The primary frequency modulation droop characteristic is realized by setting a frequency and active power broken line function, namely:

wherein P represents a full-field power target value which needs to be reached by primary frequency modulation, and the unit is MW; f (f) _d Representing a primary frequency modulation dead zone, wherein the unit is Hz; f (f) _N The rated frequency of the power grid system is represented, and the unit is Hz; p (P) _N Rated power in MW; delta% represents a primary frequency modulation difference adjustment coefficient of the new energy; p (P) ₀ Representing a primary frequency modulation full-field active initial value, wherein the unit is MW; f represents the current actual frequency of the grid.

For example, the dead zone of primary frequency modulation is set to 0.05Hz, the difference adjustment coefficient is set to 5%, and the maximum power limiting limit of primary frequency modulation power is set to 6%P _N Regulating maximum power limiting limit to 10% P under primary frequency modulation power _N In the case of a wind farm participating in grid primary frequency modulation, the droop curve may be as shown in fig. 2.

Fig. 3 shows a flowchart of a method of active regulation of a wind farm according to an exemplary embodiment of the present disclosure.

As an example, the active regulation method of a wind farm according to an exemplary embodiment of the present disclosure may be performed by a farm-level controller of the wind farm, which may be, for example, a VMP.

A wind farm may include a plurality of wind power generation sets. The wind generating set of the wind farm is connected to the power grid in a proper mode.

Referring to fig. 3, in step S10, a full-field active adjustment amount that requires wind farm adjustment is determined every first preset time period from reaching a primary frequency modulation triggering condition.

Full farm active adjustment, i.e., active power delta, requiring wind farm adjustment. It should be appreciated that the full field active adjustment amount required for wind farm adjustment may be greater than 0 or less than 0, where a full field active adjustment amount required for wind farm adjustment is greater than 0, i.e., where wind farm increase active power output is required, and where a full field active adjustment amount required for wind farm adjustment is less than 0, i.e., where wind farm decrease active power output is required.

As an example, the primary frequency modulation trigger condition may be that the grid tie frequency of the wind farm exceeds the primary frequency modulation dead zone.

For example only, the first preset duration may be 20ms. The first preset duration may be set to an appropriate value according to the actual situation and specific requirements.

As an example, in the case where automatic generation control AGC is currently required for a wind farm, the full farm active adjustment amount may be: the sum of the AGC full field active adjustment amount for implementing AGC and the primary frequency modulation full field active adjustment amount for implementing primary frequency modulation. Otherwise, the full-field active adjustment may be: the full-field active adjustment quantity of the primary frequency modulation is used for realizing the primary frequency modulation.

According to an exemplary embodiment of the present disclosure, considering that in the prior art, only one of the AGC device and the primary frequency modulation control device can control the wind turbine generator set at the same time, the cooperative control of the AGC and the primary frequency modulation cannot be achieved. The present disclosure proposes to superimpose the AGC full-field active adjustment amount with the primary frequency modulation full-field active adjustment amount to obtain a comprehensive full-field active adjustment amount, and control a fan of the wind farm based on the comprehensive full-field active adjustment amount, that is, simultaneously perform AGC and primary frequency modulation, so as to satisfy the requirement of AGC and primary frequency modulation cooperative control.

It should be appreciated that the primary full field active adjustment may be calculated every first predetermined time period. Under the condition that automatic power generation control AGC is required to be performed on a wind power plant at present, the primary frequency modulation full-field active adjustment quantity can be calculated every a first preset time length, the updated AGC full-field active adjustment quantity is obtained, and the updated full-field active adjustment quantity is obtained.

As an example, the calculated primary frequency modulation full field active adjustment may be:

in step S20, it is determined whether a preset condition is satisfied based on the full-field active adjustment amount.

As an example, the preset condition may include: the first preset condition or the second preset condition. It should be appreciated that the preset conditions may be considered to be met when one of the first preset condition and the second preset condition is met.

The first preset condition may be: the full-field active adjustment amount determined at this time is different from the full-field active adjustment amount determined at the last time, and the active adjustment amount has reached a second preset time period from the last issuing unit.

The second preset condition may be: the current determined full-field active adjustment quantity is the same as the last determined full-field active adjustment quantity, the active adjustment quantity of the single machine issued last time reaches a third preset duration, and the difference between the current full-field actual power and the full-field power target value which is required to be reached by the active adjustment quantity of the single machine issued last time exceeds a full-field power control precision dead zone. For example, the full-field power target value that needs to be reached by the last single-machine active adjustment may be: and the sum of the full-field active adjustment quantity required to be adjusted when the active adjustment quantity of the single machine is issued last time and the initial value of the full-field active of the primary frequency modulation.

As an example, the second preset time period may be longer than the first preset time period, and the third preset time period may be longer than the first preset time period. As an example, the third preset time period may be longer than the second preset time period.

It should be understood that step S20 is executed to make a judgment every time after the full-field active adjustment amount (i.e., the full-field active adjustment amount determined this time) is determined in step S10.

When it is determined in step S20 that the preset condition is satisfied, step S30 is performed to determine full-field adjustable standby power.

In step S40, based on the full-field active adjustment amount and the full-field adjustable standby power, a single-machine active adjustment amount corresponding to each wind power generator set of the wind power plant is determined.

In step S50, corresponding active adjustment amounts of the single machines are respectively issued to each wind turbine generator set, so as to control each wind turbine generator set to perform active adjustment.

As an example, the method of active regulation of a wind farm according to an exemplary embodiment of the present disclosure may further include: and when the frequency of the grid-connected point of the wind power plant returns to the primary frequency modulation dead zone, ending executing the active regulation method.

According to the exemplary embodiments of the present disclosure, control accuracy can be improved and response time can be shortened by closed-loop control according to full-field actual power during frequency modulation. Especially, after the primary frequency modulation is triggered, the control device is continuously in a primary frequency modulation state, and under the scene of long-time non-exit, even if the wind speed is unstable or the change is overlarge in the control process, the control precision can be ensured.

An exemplary embodiment of the manner in which the AGC full field active adjustment amount is determined will be described below.

In one embodiment, the AGC full field active adjustment amount may be determined as: the difference between the current AGC execution plan value and the primary frequency modulation full field active initial value; alternatively, the AGC full field active adjustment amount may be determined as: the difference between the current AGC execution plan value and the AGC execution plan value when the chirping trigger condition is reached (i.e., the chirping trigger time). The current AGC execution plan value is the AGC execution plan value updated last time.

The AGC execution plan value is the smaller value of the AGC scheduling plan value and the active scheduling plan value of the wind power plant, and the AGC scheduling plan value is the active scheduling plan value of the network side. As an example, the AGC scheduling plan value and the AGC execution plan value issued by the AGC device such as EMP may be received from the AGC device, for example, the issued AGC scheduling plan value may be the original active scheduling plan value received by the AGC device directly forwarded by the AGC device, or may be an active scheduling plan value obtained by dividing the original active scheduling plan value received by the AGC device, and the AGC device may issue the active scheduling plan value obtained by dividing one division in sequence every other issue period.

As an example, there may be at least one automatic power generation control mode, for example, the type of automatic power generation control mode may include at least one of: a first AGC mode, a second AGC mode, a third AGC mode. One of the above modes may be used when a primary frequency modulation trigger condition is reached.

As an example, in the first AGC mode, the scheduling (e.g., an EMP or other AGC device) may issue an AGC scheduling plan value once at a fourth preset time interval, and the active adjustment method of the wind farm according to the exemplary embodiment of the present disclosure may further include: and receiving the issued AGC scheduling plan value, and splitting the AGC scheduling plan value according to the slope to obtain the AGC full-field active adjustment quantity of each control sub-period. The first control sub-period may be entered first and when the duration of a single control sub-period is reached, the next control sub-period is entered sequentially. For example, the fourth preset time period may be 5 minutes. For example, the duration of a single control sub-period may be 5 seconds or 10 seconds.

As an example, in the second AGC mode, the schedule may issue an AGC schedule plan value once at a fifth preset time interval. For example, the fifth preset duration may be 4 seconds.

As an example, in the third AGC mode, the scheduling is not controlled, and is self-controlled in situ.

As an example, the AGC full field active adjustment amount may be determined as: the difference between the current AGC performance plan value and the full-field active initial value of the primary frequency modulation, or the difference between the current AGC performance plan value and the AGC performance plan value when the primary frequency modulation trigger condition is reached.

As an example, the AGC full field active adjustment amount may be determined with the second AGC mode as: the difference between the current AGC performance plan value and the full-field active initial value of the primary frequency modulation, or the difference between the current AGC performance plan value and the AGC performance plan value when the primary frequency modulation trigger condition is reached.

As an example, the AGC full field active adjustment amount may be determined with the third AGC mode as: the difference between the current AGC performance plan value and the full-field active initial value of the primary frequency modulation, or the difference between the current AGC performance plan value and the AGC performance plan value when the primary frequency modulation trigger condition is reached.

In another embodiment, the number of remaining control sub-periods for the AGC scheduling value that is issued last time may be determined according to the time from the issue period of the next AGC scheduling value, and the ratio of the remaining portion to be executed of the AGC scheduling value that is issued last time to the number of remaining control sub-periods is determined as the adjustment amount of the single remaining control sub-period; when the i-th remaining control sub-period is present, the sum of (i-th adjustment amount of the single remaining control sub-period) and the AGC compensation value is determined as the AGC full-field active adjustment amount. i is an integer greater than 0, and the start value of i is 1. The AGC compensation value is the difference between the last AGC schedule value of the last issued AGC schedule value and the full-field active initial value of the primary frequency modulation. For example, the AGC full field active adjustment amount may be determined in accordance with this embodiment with the first AGC mode and the AGC execution plan value not less than the AGC schedule plan value.

As an example, the ratio between the time of the next AGC schedule value's issue period and the duration of a single control sub-period may be taken as the number of remaining control sub-periods for the last issued AGC schedule value.

It should be appreciated that the amount of adjustment for a single remaining control sub-period may be determined for the first time when a primary frequency modulation trigger condition is reached. The adjustment amount for a single remaining control sub-period may then be determined each time an issued AGC schedule value is received.

As an example, in the case where the adjustment amount of a single remaining control sub-period is determined for the first time after reaching the primary frequency modulation trigger condition, the remaining to-be-executed portion of the AGC scheduling value that was issued last time may be: the difference between the most recently issued AGC schedule value and the primary full field active initial value. As an example, the AGC compensation value may be 0 in the case where the adjustment amount of a single remaining control sub-period is determined for the first time after the primary frequency modulation trigger condition is reached.

As an example, in the case where the adjustment amount of a single remaining control sub-period is not determined for the first time after reaching the primary frequency modulation trigger condition, the remaining to-be-executed portion of the AGC scheduling plan value that was issued last time may be: the difference between the last AGC scheduling plan value issued and the last AGC scheduling plan value. The last AGC schedule value of the last issued AGC schedule value is the last AGC schedule value issued the last time.

As an example, when the time from the next AGC schedule value's issue period is less than the duration of a single control subcycle, the AGC full field active adjustment amount may be determined as: the difference between the most recently issued AGC schedule value and the primary full field active initial value.

According to an exemplary embodiment of the present disclosure, considering that the chirped full field droop control calculation is to calculate the chirped full field active adjustment (i.e., PFR instructions) based on the chirped full field active initial value P0, the AGC full field active adjustment is also calculated based on P0 when calculating the AGC full field active adjustment, thereby facilitating coordinated superposition in the same dimension.

An exemplary embodiment of step S30 will be described below.

The full field adjustable standby power may include: the standby power is adjusted in full-field up and in full-field down.

As an example, step S30 may include: the method comprises the steps of adjusting reserve power in a variable pitch mode, adjusting reserve power in an inertia mode and adjusting reserve power in a rotor kinetic energy mode of each wind generating set of a wind power plant, and determining full-field up-adjustment reserve power; and the standby power is adjusted in a pitching mode, the standby power is adjusted in an inertia mode and the standby power is adjusted in a braking resistance mode based on each wind power generator set of the wind power plant, and the full-field down-adjustment standby power is determined.

The variable pitch mode of the wind generating set is used for up-regulating standby power, namely the active power quantity which can be increased by the wind generating set through variable pitch operation; the method for up-regulating the standby power in the rotor kinetic energy mode of the wind generating set refers to the active power quantity which can be increased by changing the rotor kinetic energy of the wind generating set; the inertia mode of the wind generating set is used for up-regulating standby power, namely the active power quantity which can be increased by the inertia of the wind generating set. As an example, the inertia mode of the wind turbine generator system may be determined to up-regulate the standby power based on the generator set inertia coefficient, the rated power, and the current actual power of the wind turbine generator system.

For example, the pitch up-regulation reserve power of a wind farm may be: and the sum of standby power is adjusted in a variable pitch mode of each wind generating set in the wind power plant. For example, the inertia mode of the wind farm may be: and the sum of standby power is adjusted in an inertia mode of each wind generating set in the wind power plant. For example, the rotor kinetic energy up-regulation reserve power of a wind farm may be: and the sum of standby power is adjusted in a rotor kinetic energy mode of each wind generating set in the wind power plant. The full-field up-regulated standby power may be: the pitch mode of the wind power plant is used for up-regulating the standby power, the inertia mode of the wind power plant is used for up-regulating the standby power, and the rotor kinetic energy mode of the wind power plant is used for up-regulating the sum of the standby power, namely the sum of the up-regulating standby power of each wind power generator set of the wind power plant.

The step of adjusting standby power in a pitch-variable mode of the wind generating set refers to the active power quantity which can be reduced by the wind generating set through pitch-variable operation; the method for adjusting the standby power in a braking resistance mode of the wind generating set refers to the active power quantity which can be reduced by the wind generating set through the consumption of the braking resistance; the inertia mode of the wind generating set is used for adjusting standby power, namely the active power quantity of the wind generating set which can be reduced through inertia. As an example, the inertia mode of the wind turbine generator system may be determined to adjust the standby power based on the generator system inertia coefficient, the rated power, and the current actual power of the wind turbine generator system.

For example, the pitch down-regulation of reserve power for a wind farm may be: and the sum of standby power is regulated in a variable pitch mode of each wind generating set in the wind power plant. For example, the inertia mode of the wind farm may be: and the sum of standby power is regulated in an inertia mode of each wind generating set in the wind power plant. For example, the braking resistance mode of the wind farm can be used for adjusting standby power: and the sum of standby power is regulated in a braking resistance mode of each wind generating set in the wind power plant. The full field down-regulated standby power may be: the method comprises the steps of adjusting standby power in a pitch mode of a wind power plant, adjusting the standby power in an inertia mode of the wind power plant, and adjusting the sum of the standby power in a braking resistance mode of the wind power plant.

As an example, the pitch up-regulation standby power of the wind generating set with the current theoretical power being smaller than the current actual power may be: the wind generating set adjusts the sum of the standby power and the up-adjustment margin up based on the current actual power in a pitch mode. The up margin is greater than 0, for example, the up margin may be 200kW. And (3) up-regulating the standby power in a variable-pitch mode based on the current actual power, namely up-regulating the standby power in the variable-pitch mode obtained by calculating the current actual power of the wind generating set.

As an example, the theoretical power of the wind generating set may be the power value that the wind turbine should reach at the current wind speed, which is obtained through ultra-short-term wind turbine power prediction. As an example, the original theoretical power of each wind power generator set of the wind farm may be obtained from the EMP, and then the original theoretical power is processed based on the pitch angle and the actual power to obtain the final theoretical power. For example, after deriving the original theoretical power of each wind power generator set of a wind farm from the EMP, the following process may be performed: when the average pitch angle of all blades of the wind generating set is smaller than a preset threshold value, determining the theoretical power of the wind generating set as: the actual power of the wind generating set; when the average pitch angle of all blades of the wind generating set is larger than or equal to a preset threshold value and the actual power is larger than the rated power, determining the theoretical power of the wind generating set as: the actual power of the wind generating set; when the average pitch angle of all blades of the wind generating set is larger than or equal to a preset threshold value, the actual power is smaller than or equal to the rated power, and the actual power is smaller than 0, determining the theoretical power of the wind generating set as: 0; when the average pitch angle of all blades of the wind generating set is larger than or equal to a preset threshold value, the actual power is smaller than or equal to the rated power, and the actual power is larger than or equal to 0, determining the theoretical power of the wind generating set as: the original theoretical power of the typhoon generator set obtained from the EMP.

According to the embodiment of the disclosure, the up-regulation standby power of the wind generating set with theoretical power smaller than actual power based on the pitch mode obtained by actual power calculation can be corrected, and the calculation accuracy of the up-regulation standby power of the pitch mode of the wind generating set is improved.

An exemplary embodiment of step S40 will be described below in conjunction with fig. 4.

Referring to fig. 4, in step S401, the full-field active adjustment amount is corrected based on the full-field actual power and the primary frequency modulation full-field active initial value, and the corrected full-field active adjustment amount based on the full-field actual power is obtained.

As an example, the full farm actual power may be the actual power of a grid connection point of the wind farm or the sum of the actual powers of the individual wind turbine generators of the wind farm.

As an example, a sum of the primary frequency modulated full field active initial value and the full field active adjustment may be determined, and a difference between the sum and the full field actual power may be determined as the corrected full field active adjustment.

According to the exemplary embodiment of the present disclosure, it is considered that the field level integrated instruction (i.e., the full-field active adjustment amount) is calculated based on P0, but after long-term adjustment, the deviation between the actual power and P0 is large, so that the full-field active adjustment amount based on the field level P0 is converted into the full-field active adjustment amount based on the actual power, so that the full-field active adjustment amount is corrected, thereby improving the accuracy of control.

As an example, the corrected full field active adjustment amount deltaseal may be obtained by:

DeltPReal＝WTSumMeasP0+BlockLogicDeltP–WTSumRealTimePower

(2)

wherein WTSumMeasP0 represents the sum of the actual power of each wind turbine generator set when primary frequency modulation is triggered, blockLogicDeltP represents the full-field active adjustment quantity when the wind turbine generator set is not corrected, and WTSumRealTimePower represents the sum of the actual power of each wind turbine generator set at present.

As another example, the corrected full field active adjustment amount deltaseal may be obtained by:

DeltPReal＝PCCMeasP0+BlockLogicDeltP–PCCRealTimePower(3)

wherein PCCMeasP0 represents the actual power of the grid-connected point when the primary frequency modulation is triggered, blockLogicDeltP represents the full-field active adjustment quantity when the primary frequency modulation is not corrected, and PCCRealTimePower represents the actual power of the current grid-connected point.

As an example, the actual power of the grid-connected point may be preferentially taken as the full-field actual power, but when the grid-connected point is abnormal, the total sum of the actual powers of the wind turbine generator sets is switched to be taken as the full-field actual power. For example, a grid-tie anomaly may be determined when the actual power of the grid-tie point is less than the sum of the actual powers of the wind turbine generators and the difference is greater than 10% pn, and this condition persists for a period of time.

In step S402, a single active adjustment of each wind turbine generator set is determined based on the corrected full-farm active adjustment and the full-farm adjustable standby power.

It should be appreciated that each wind turbine generator set may be assigned a single active modulation requiring its modulation based on the modified full-farm active modulation and full-farm adjustable standby power in an appropriate manner, which is not limiting in this disclosure.

In step S403, for each wind generating set, based on the actual power of the wind generating set and the primary frequency modulation active initial value, the single-machine active adjustment amount of the wind generating set is corrected, so as to obtain a corrected single-machine active adjustment amount based on the primary frequency modulation active initial value, and then the corrected single-machine active adjustment amount based on the primary frequency modulation active initial value is issued.

The primary frequency modulation active initial value of the wind generating set is the actual power of the wind generating set when the primary frequency modulation is triggered.

As an example, for each wind generating set, on the basis of the single-machine active adjustment quantity of the wind generating set, the difference between the actual power of the wind generating set and the primary frequency modulation active initial value can be superimposed, so as to obtain the corrected single-machine active adjustment quantity based on the primary frequency modulation active initial value.

The present disclosure contemplates: and when the primary frequency modulation control is short, the control of the later stage of the unit is performed on the basis of the real-time power of the unit at the triggering moment of the primary frequency modulation control. However, after the long-time primary frequency modulation control is changed due to different application scenes, the control process is long, the full-field active adjustment quantity obtained based on the initial value of the primary frequency modulation full-field active is corrected to the full-field active adjustment quantity based on the full-field actual power, and in the distribution process, the up-down adjustment standby power capacity of each fan is obtained based on the current actual power, so that the single-machine active adjustment quantity distributed to each fan is not based on the initial value of the primary frequency modulation active, but in order to enable the fan not to modify the program, the compatibility of the short-time primary frequency modulation control and the long-time primary frequency modulation control is met, and therefore the single-machine active adjustment quantity based on the actual power of each fan is corrected to the single-machine active adjustment quantity based on the initial value of the primary frequency modulation active. After the corrected single-machine active adjustment quantity is issued to the fan, the execution effect is one dimension.

According to the exemplary embodiment of the present disclosure, the calculation accuracy of the up-regulation standby power is improved; the primary frequency modulation is triggered for a long time, and even if the wind speed is unstable or the change is overlarge in the control process, the whole field regulation and control precision can be ensured; the requirement of the power grid for simultaneous control of primary frequency modulation and AGC scheduling is met; on the basis of no modification of the wind turbine generator system program, the control requirements of short-time control and long-time control can be simultaneously met.

As shown in fig. 5, an active power adjustment device of a wind farm according to an exemplary embodiment of the present disclosure includes: full-field active adjustment amount determining unit 10, judging unit 20, standby power determining unit 30, stand-alone active adjustment amount determining unit 40, issuing unit 50.

Specifically, the full-field active adjustment amount determination unit 10 is configured to determine the full-field active adjustment amount that requires wind farm adjustment every first preset time period from the time when the primary frequency modulation triggering condition is reached.

The judging unit 20 is configured to determine whether a preset condition is satisfied based on the full-field active adjustment amount.

The standby power determining unit 30 is configured to determine the full-field adjustable standby power when the preset condition is satisfied.

The stand-alone active adjustment amount determination unit 40 is configured to determine a respective stand-alone active adjustment amount for each wind turbine generator set of the wind farm based on the full-field active adjustment amount and the full-field adjustable standby power.

The issuing unit 50 is configured to issue corresponding individual active adjustment amounts to each of the wind turbine generator sets, respectively, to control each of the wind turbine generator sets to perform active adjustment.

As an example, in the case where automatic generation control AGC is currently required for a wind farm, the full farm active adjustment amount may be: the sum of the AGC full field active adjustment amount for implementing AGC and the primary frequency modulation full field active adjustment amount for implementing primary frequency modulation.

As an example, the preset condition may include: the first preset condition or the second preset condition, wherein the first preset condition is as follows: the determined full-field active adjustment quantity is different from the last determined full-field active adjustment quantity, and the active adjustment quantity of the single machine issued last time reaches a second preset duration; the second preset condition is as follows: the determined full-field active adjustment quantity is the same as the last determined full-field active adjustment quantity, the active adjustment quantity of the single machine issued last time reaches a third preset duration, and the difference between the full-field actual power and the full-field power target value which is required to be reached by the active adjustment quantity of the single machine issued last time exceeds a full-field power control precision dead zone.

As an example, the stand-alone active adjustment amount determination unit 40 may be configured to: based on the full-field actual power and the primary frequency modulation full-field active initial value, correcting the full-field active adjustment quantity to obtain a corrected full-field active adjustment quantity based on the full-field actual power; determining a single-machine active adjustment quantity of each wind generating set based on the corrected full-field active adjustment quantity and full-field adjustable standby power; and correcting the single-machine active adjustment quantity of each wind generating set based on the actual power and the primary frequency modulation active initial value of the wind generating set to obtain the corrected single-machine active adjustment quantity based on the primary frequency modulation active initial value.

As an example, the stand-alone active adjustment amount determination unit 40 may be configured to: and determining a sum value of the primary frequency modulation full-field active initial value and the full-field active adjustment quantity, and determining a difference value between the sum value and the full-field actual power as a corrected full-field active adjustment quantity.

As an example, the stand-alone active adjustment amount determination unit 40 may be configured to: and aiming at each wind generating set, superposing the difference between the actual power of the wind generating set and the primary frequency modulation active initial value on the basis of the single-machine active adjustment quantity of the wind generating set to obtain the corrected single-machine active adjustment quantity based on the primary frequency modulation active initial value.

As an example, the full farm actual power may be the actual power of a grid connection point or the sum of the actual power of each wind turbine generator set of the wind farm.

As an example, the AGC full field active adjustment amount may be determined by: the AGC full field active adjustment is determined as: the difference between the current AGC performance plan value and the full-field active initial value of the primary frequency modulation, or the difference between the current AGC performance plan value and the AGC performance plan value when the primary frequency modulation trigger condition is reached.

As an example, the AGC full field active adjustment amount may be determined by: determining the number of remaining control sub-periods for the AGC scheduling value issued last time according to the time of the issuing period from the next AGC scheduling value, and determining the ratio of the remaining part to be executed of the AGC scheduling value issued last time to the number of remaining control sub-periods as the adjustment quantity of a single remaining control sub-period; and when the AGC compensation value is in the ith residual control subcycle, determining the sum of the AGC compensation value and the adjustment quantity of the i single residual control subcycle as the AGC full-field active adjustment quantity, wherein the AGC compensation value is the difference value between the last AGC scheduling plan value of the AGC scheduling plan value issued last time and the active initial value of the primary frequency modulation full-field, the AGC execution plan value is the smaller value of the AGC scheduling plan value and the active scheduling value of the wind power plant, and the AGC scheduling plan value is the active scheduling plan value of the network side.

As an example, in the case where the adjustment amount of a single remaining control sub-period is determined for the first time after reaching the primary frequency modulation trigger condition, the remaining to-be-executed portion of the AGC scheduling value that was issued last time may be: the difference between the latest issued AGC scheduling plan value and the primary frequency modulation full-field active initial value; in the case that the adjustment amount of a single remaining control sub-period is not determined for the first time after the primary frequency modulation triggering condition is reached, the remaining to-be-executed portion of the AGC scheduling plan value that is issued last time may be: the difference between the last AGC scheduling plan value issued and the last AGC scheduling plan value.

As an example, the full-field adjustable standby power may include: full-field up-regulation of standby power and full-field down-regulation of standby power; wherein the standby power determining unit 30 may be configured to: the method comprises the steps of adjusting reserve power in a variable pitch mode, adjusting reserve power in an inertia mode and adjusting reserve power in a rotor kinetic energy mode of each wind generating set of a wind power plant, and determining full-field up-adjustment reserve power; the method comprises the steps of adjusting standby power in a variable pitch mode, adjusting standby power in an inertia mode and adjusting standby power in a braking resistance mode of each wind generating set based on a wind power plant, and determining full-field down-adjustment standby power, wherein the variable pitch mode of the wind generating set with theoretical power smaller than actual power is as follows: the wind generating set is used for up-regulating the sum of standby power and up-regulating margin based on a pitching mode of actual power, wherein the up-regulating margin is larger than 0.

As an example, the active modulation device may be provided in a controller of a wind farm.

It should be appreciated that the specific process performed by the active power adjustment device of the wind farm according to the exemplary embodiment of the present disclosure has been described in detail with reference to fig. 1 to 4, and the relevant details will not be repeated here.

It should be understood that the individual units in the active modulation device of a wind farm according to exemplary embodiments of the present disclosure may be implemented as hardware components and/or as software components. The individual units may be implemented, for example, using a Field Programmable Gate Array (FPGA) or an Application Specific Integrated Circuit (ASIC), depending on the processing performed by the individual units as defined.

Exemplary embodiments of the present disclosure provide a computer readable storage medium storing a computer program, which when executed by a processor, causes the processor to perform the method of active power adjustment of a wind farm as described in the above exemplary embodiments. The computer readable storage medium is any data storage device that can store data which can be read by a computer system. Examples of the computer readable storage medium include: read-only memory, random access memory, compact disc read-only, magnetic tape, floppy disk, optical data storage device, and carrier waves (such as data transmission through the internet via wired or wireless transmission paths).

An active power conditioning device of a wind farm according to an exemplary embodiment of the present disclosure includes: a processor (not shown) and a memory (not shown), wherein the memory stores a computer program which, when executed by the processor, causes the processor to perform the method of active regulation of a wind farm as described in the above exemplary embodiments.

Although a few exemplary embodiments of the present disclosure have been shown and described, it would be appreciated by those skilled in the art that changes may be made in these embodiments without departing from the principles and spirit of the disclosure, the scope of which is defined in the claims and their equivalents.

Claims

1. A method of active regulation of a wind farm, comprising:

starting from reaching a primary frequency modulation triggering condition, determining a full-field active adjustment quantity required to be adjusted by the wind power plant every a first preset time length, and determining whether the preset condition is met or not based on the full-field active adjustment quantity;

when the preset condition is met, determining full-field adjustable standby power;

based on the full-field active adjustment quantity and the full-field adjustable standby power, determining a single-machine active adjustment quantity corresponding to each wind generating set of the wind power plant;

And respectively issuing corresponding single machine active adjustment quantity to each wind generating set so as to control each wind generating set to perform active adjustment.

2. The active power adjustment method according to claim 1, wherein in the case where automatic power generation control AGC is currently required for the wind farm, the full-field active power adjustment amount is: the sum of the AGC full field active adjustment amount for implementing AGC and the primary frequency modulation full field active adjustment amount for implementing primary frequency modulation.

3. The active power conditioning method of claim 1, wherein the preset conditions include: a first preset condition or a second preset condition,

the first preset condition is as follows: the determined full-field active adjustment quantity is different from the last determined full-field active adjustment quantity, and the active adjustment quantity of the single machine issued last time reaches a second preset duration;

the second preset condition is as follows: the determined full-field active adjustment quantity is the same as the last determined full-field active adjustment quantity, the active adjustment quantity of the single machine issued last time reaches a third preset duration, and the difference between the full-field actual power and the full-field power target value which is required to be reached by the active adjustment quantity of the single machine issued last time exceeds a full-field power control precision dead zone.

4. The method of active power adjustment according to claim 1, wherein the step of determining a respective stand-alone active power adjustment for each wind turbine generator set of the wind farm based on the full-field active power adjustment and the full-field adjustable standby power comprises:

based on the full-field actual power and the primary frequency modulation full-field active initial value, correcting the full-field active adjustment quantity to obtain a corrected full-field active adjustment quantity based on the full-field actual power;

determining a single-machine active adjustment quantity of each wind generating set based on the corrected full-field active adjustment quantity and full-field adjustable standby power;

and correcting the single-machine active adjustment quantity of each wind generating set based on the actual power and the primary frequency modulation active initial value of the wind generating set to obtain the corrected single-machine active adjustment quantity based on the primary frequency modulation active initial value.

5. The method of active power adjustment according to claim 4, wherein the step of obtaining a corrected full-field active power adjustment amount based on full-field actual power comprises:

and determining a sum value of the primary frequency modulation full-field active initial value and the full-field active adjustment quantity, and determining a difference value between the sum value and the full-field actual power as a corrected full-field active adjustment quantity.

6. The method of claim 4, wherein the step of obtaining a corrected single-machine active adjustment amount based on the primary frequency modulation active initial value comprises:

and aiming at each wind generating set, superposing the difference between the actual power of the wind generating set and the primary frequency modulation active initial value on the basis of the single-machine active adjustment quantity of the wind generating set to obtain the corrected single-machine active adjustment quantity based on the primary frequency modulation active initial value.

7. An active power conditioning method according to any of claims 3 to 5, characterized in that the full-field actual power is the sum of the actual power of the grid-connected point or the actual power of each wind power generator set of the wind farm.

8. The active adjustment method according to claim 1, characterized in that the AGC full-field active adjustment amount is determined by:

the AGC full field active adjustment is determined as: the difference between the current AGC execution plan value and the full-field active initial value of primary frequency modulation, or the difference between the current AGC execution plan value and the AGC execution plan value when the primary frequency modulation triggering condition is reached;

or,

determining the number of remaining control sub-periods for the AGC scheduling value issued last time according to the time of the issuing period from the next AGC scheduling value, and determining the ratio of the remaining part to be executed of the AGC scheduling value issued last time to the number of remaining control sub-periods as the adjustment quantity of a single remaining control sub-period;

When the i-th remaining control sub-period is present, determining the sum of the AGC compensation value and the adjustment of i-th single remaining control sub-period as the AGC full-field active adjustment,

wherein the AGC compensation value is the difference between the last AGC scheduling plan value of the last issued AGC scheduling plan value and the active initial value of the full field of primary frequency modulation,

the AGC execution plan value is the smaller value of the AGC scheduling plan value and the active scheduling plan value of the wind power plant, and the AGC scheduling plan value is the active scheduling plan value of the network side.

9. The method of active power conditioning according to claim 8, wherein,

under the condition that the adjustment quantity of a single remaining control sub-period is determined for the first time after the primary frequency modulation triggering condition is reached, the remaining to-be-executed part of the AGC scheduling plan value issued last time is as follows: the difference between the latest issued AGC scheduling plan value and the primary frequency modulation full-field active initial value;

in the case that the adjustment amount of a single remaining control sub-period is not determined for the first time after the primary frequency modulation triggering condition is reached, the remaining to-be-executed part of the AGC scheduling plan value issued last time is: the difference between the last AGC scheduling plan value issued and the last AGC scheduling plan value.

10. The active power conditioning method of claim 1, wherein the full-field adjustable standby power comprises: full-field up-regulation of standby power and full-field down-regulation of standby power;

wherein the step of determining the full field adjustable standby power comprises:

the method comprises the steps of adjusting reserve power in a variable pitch mode, adjusting reserve power in an inertia mode and adjusting reserve power in a rotor kinetic energy mode of each wind generating set of a wind power plant, and determining full-field up-adjustment reserve power;

the standby power is adjusted in a pitch mode, the standby power is adjusted in an inertia mode and the standby power is adjusted in a braking resistance mode based on each wind generating set of the wind power plant, the standby power is adjusted in a full-field mode is determined,

the variable pitch mode of the wind generating set with theoretical power smaller than actual power is used for up-regulating standby power, and the variable pitch mode is as follows: the wind generating set is used for up-regulating the sum of standby power and up-regulating margin based on a pitching mode of actual power, wherein the up-regulating margin is larger than 0.

11. An active power conditioning device for a wind farm, comprising:

the full-field active adjustment quantity determining unit is configured to determine full-field active adjustment quantity required to be adjusted by the wind power plant every a first preset time period from the time when the primary frequency modulation triggering condition is reached;

A judging unit configured to determine whether a preset condition is satisfied based on the full-field active adjustment amount;

a standby power determining unit configured to determine full-field adjustable standby power when the preset condition is satisfied;

a single-machine active adjustment amount determining unit configured to determine a single-machine active adjustment amount corresponding to each wind power generator set of the wind power plant based on the full-field active adjustment amount and the full-field adjustable standby power;

and the issuing unit is configured to issue corresponding single-machine active adjustment amounts to each wind generating set respectively so as to control each wind generating set to perform active adjustment.

12. The active modulation device of claim 11, wherein the active modulation device is disposed in a controller of a wind farm.

13. A computer readable storage medium storing a computer program, characterized in that the computer program, when executed by a processor, causes the processor to perform the method of active regulation of a wind farm according to any of claims 1 to 10.

14. An active power conditioning device for a wind farm, the active power conditioning device comprising:

a processor;

memory storing a computer program which, when executed by a processor, causes the processor to perform the active modulation method of a wind farm according to any of claims 1 to 10.

15. The active modulation device of claim 14, wherein the active modulation device is disposed in a controller of a wind farm.