WO2020001559A1 - 风力发电机组的控制方法、控制装置、控制器及控制系统 - Google Patents

风力发电机组的控制方法、控制装置、控制器及控制系统 Download PDF

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Publication number
WO2020001559A1
WO2020001559A1 PCT/CN2019/093375 CN2019093375W WO2020001559A1 WO 2020001559 A1 WO2020001559 A1 WO 2020001559A1 CN 2019093375 W CN2019093375 W CN 2019093375W WO 2020001559 A1 WO2020001559 A1 WO 2020001559A1
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Prior art keywords
wind
wind direction
wind turbine
downstream
upstream
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PCT/CN2019/093375
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English (en)
French (fr)
Inventor
于迟
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北京金风科创风电设备有限公司
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Application filed by 北京金风科创风电设备有限公司 filed Critical 北京金风科创风电设备有限公司
Priority to US17/043,478 priority Critical patent/US11493023B2/en
Priority to AU2019296291A priority patent/AU2019296291B2/en
Priority to EP19827431.8A priority patent/EP3770423B1/en
Publication of WO2020001559A1 publication Critical patent/WO2020001559A1/zh

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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F03—MACHINES OR ENGINES FOR LIQUIDS; WIND, SPRING, OR WEIGHT MOTORS; PRODUCING MECHANICAL POWER OR A REACTIVE PROPULSIVE THRUST, NOT OTHERWISE PROVIDED FOR
    • F03D—WIND MOTORS
    • F03D7/00—Controlling wind motors 
    • F03D7/02—Controlling wind motors  the wind motors having rotation axis substantially parallel to the air flow entering the rotor
    • F03D7/04—Automatic control; Regulation
    • F03D7/042—Automatic control; Regulation by means of an electrical or electronic controller
    • F03D7/048—Automatic control; Regulation by means of an electrical or electronic controller controlling wind farms
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F03—MACHINES OR ENGINES FOR LIQUIDS; WIND, SPRING, OR WEIGHT MOTORS; PRODUCING MECHANICAL POWER OR A REACTIVE PROPULSIVE THRUST, NOT OTHERWISE PROVIDED FOR
    • F03D—WIND MOTORS
    • F03D7/00—Controlling wind motors 
    • F03D7/02—Controlling wind motors  the wind motors having rotation axis substantially parallel to the air flow entering the rotor
    • F03D7/0204—Controlling wind motors  the wind motors having rotation axis substantially parallel to the air flow entering the rotor for orientation in relation to wind direction
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F03—MACHINES OR ENGINES FOR LIQUIDS; WIND, SPRING, OR WEIGHT MOTORS; PRODUCING MECHANICAL POWER OR A REACTIVE PROPULSIVE THRUST, NOT OTHERWISE PROVIDED FOR
    • F03D—WIND MOTORS
    • F03D7/00—Controlling wind motors 
    • F03D7/02—Controlling wind motors  the wind motors having rotation axis substantially parallel to the air flow entering the rotor
    • F03D7/022—Adjusting aerodynamic properties of the blades
    • F03D7/0224—Adjusting blade pitch
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05B—INDEXING SCHEME RELATING TO WIND, SPRING, WEIGHT, INERTIA OR LIKE MOTORS, TO MACHINES OR ENGINES FOR LIQUIDS COVERED BY SUBCLASSES F03B, F03D AND F03G
    • F05B2260/00—Function
    • F05B2260/70—Adjusting of angle of incidence or attack of rotating blades
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05B—INDEXING SCHEME RELATING TO WIND, SPRING, WEIGHT, INERTIA OR LIKE MOTORS, TO MACHINES OR ENGINES FOR LIQUIDS COVERED BY SUBCLASSES F03B, F03D AND F03G
    • F05B2270/00—Control
    • F05B2270/30—Control parameters, e.g. input parameters
    • F05B2270/32—Wind speeds
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05B—INDEXING SCHEME RELATING TO WIND, SPRING, WEIGHT, INERTIA OR LIKE MOTORS, TO MACHINES OR ENGINES FOR LIQUIDS COVERED BY SUBCLASSES F03B, F03D AND F03G
    • F05B2270/00—Control
    • F05B2270/30—Control parameters, e.g. input parameters
    • F05B2270/321—Wind directions
    • 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
    • Y02E10/72—Wind turbines with rotation axis in wind direction

Definitions

  • the present disclosure relates to wind power generation technology, and in particular, the present disclosure relates to a control method, a control device, a controller, and a control system for a wind turbine.
  • wind turbines cannot effectively predict environmental changes and respond quickly.
  • the wind farm in the whole site is in a stop state, if the wind speed starts to increase, each wind turbine judges the wind speed acting on itself independently. If the wind speed is higher than the set threshold within a continuous period of time, the yaw action on the wind is started and the standby state is entered.
  • each wind turbine judges the wind separately based on the wind speed and wind direction data collected by its own sensors. If the deviation from the wind is higher than a set threshold for a continuous period of time, the wind turbine starts to yaw against the wind to continue the power generation state.
  • the wind turbine's response to environmental changes is relatively slow. It often takes a long time from the judgment of each wind turbine to the start of yaw action on the wind, which results in a loss of power generation.
  • a control method for a wind turbine includes:
  • each downstream wind turbine generating unit associated with the current main wind direction is controlled.
  • a control device for a wind turbine includes:
  • the current wind direction determination module is used to obtain the current wind direction of each upstream wind turbine in the wind farm in real time
  • a main wind direction determining module configured to determine a current main wind direction to which the current wind direction of each upstream wind turbine belongs;
  • the downstream wind turbine determining module is configured to determine the current wind direction associated with each upstream wind turbine according to the association relationship between the main wind directions of the multiple upstream wind turbines and the downstream wind turbines in the main wind direction.
  • a control instruction determination module is configured to determine a control instruction for each downstream wind power generator unit associated with the current main wind direction according to a working condition state and a working condition parameter of the downstream wind power unit associated with the current main wind direction.
  • a controller for a wind turbine is provided.
  • the controller is communicatively connected with the control device described above.
  • the controller includes a receiving module for receiving the current main wind direction sent by the control device.
  • a control system for a wind turbine including: the above-mentioned control device; and the above-mentioned controller, the controller being communicatively connected with the control device.
  • a computer-readable storage medium is provided.
  • the computer-readable storage medium is used to store a computer program that, when executed by a processor, implements the above-mentioned control method of a wind turbine.
  • the embodiment of the present disclosure can use the control device of the wind turbine to sense the wind direction of the upstream wind turbine through a control algorithm, and control the pre-yaw to the wind of the downstream wind turbine in advance, so that the downstream wind turbine can respond in advance. , Can effectively reduce the loss of power generation and improve power generation efficiency.
  • FIG. 1 is a block diagram of a control system of a wind turbine according to an embodiment of the present disclosure
  • FIG. 2 is a flowchart illustrating a control method of a wind turbine according to an embodiment of the present disclosure
  • FIG. 3 is a functional block diagram of a control system of a wind turbine according to an embodiment of the present disclosure
  • FIG. 4 is a flowchart illustrating a method for determining an association relationship between a main wind direction of a plurality of upstream wind turbines and a downstream wind turbine at the main wind direction according to an embodiment of the present disclosure
  • FIG. 5 is a flowchart illustrating an operation of the group marking module in FIG. 3 according to an embodiment of the present disclosure
  • FIG. 6 is a flowchart illustrating an operation of the data analysis module in FIG. 3 according to an embodiment of the present disclosure
  • FIG. 7 is a flowchart illustrating an operation of the data analysis module in FIG. 3 according to another embodiment of the present disclosure
  • FIG. 8 is a block diagram of a control device for a wind turbine according to an embodiment of the present disclosure.
  • FIG. 9 is a block diagram of a controller of a wind turbine according to an embodiment of the present disclosure.
  • Upwind and downwind The position where the wind first blows is called the upwind position, and the position where the wind blows after is called the downwind position.
  • the upwind direction can also be understood as the direction from which the wind is blowing. Wind in nature usually blows from the upwind to the downwind.
  • Upstream wind turbine Wind turbine located in the upwind direction.
  • Downstream wind turbines Wind turbines located in the downwind direction.
  • FIG. 1 is a block diagram of a control system 10 of a wind turbine according to an embodiment of the present disclosure.
  • the control system 10 may include a central controller 101 of a wind farm and a main controller 102 of a wind turbine.
  • the main controller 102 may include a controller 1021 of the wind turbine.
  • the central controller 101 may include a control device 1011 of the wind turbine.
  • the control device 1011 and the controller 1021 can be communicatively connected.
  • FIG. 2 is a flowchart illustrating a control method of a wind turbine according to an embodiment of the present disclosure.
  • step S201 the current wind direction of each upstream wind turbine in the wind farm can be obtained (for example, through a sensor) in real time.
  • the current main wind direction to which the current wind direction of each upstream wind power generator belongs can be determined. For example, it can be determined whether the current wind direction of each upstream wind turbine belongs to the main wind direction of the upstream wind turbine according to the association relationship between the main wind direction of multiple upstream wind turbines and the downstream wind turbines in the main wind direction obtained in advance. Wind direction one. If it is determined that the current wind direction of the upstream wind turbine belongs to one of the main wind directions of the upstream wind turbine, the main wind direction to which the current wind direction belongs may be determined as the current main wind direction.
  • step S203 the downstream wind turbine associated with the current main wind direction of each upstream wind turbine may be determined according to the above-mentioned association relationship.
  • step S204 the operating conditions and operating parameters (including but not limited to time stamp, wind speed, absolute wind direction, yaw position, wind direction angle, fan status, impeller speed, Pitch angle, etc.), determine a control instruction for each downstream wind turbine associated with the current main wind direction.
  • the operating conditions and operating parameters including but not limited to time stamp, wind speed, absolute wind direction, yaw position, wind direction angle, fan status, impeller speed, Pitch angle, etc.
  • each of the downstream wind turbines associated with the current main wind direction is in a shutdown or standby state. If it is determined that each downstream wind turbine is in a stopped state or standby state, it can be determined according to the current wind direction of the upstream wind turbine belonging to the current main wind direction and the yaw position of each downstream wind turbine associated with the current main wind direction.
  • a first yaw offset value of each downstream wind power unit associated with the current main wind direction, and a yaw control command for each downstream wind power unit associated with the current main wind direction may be generated according to the first yaw deviation value.
  • each downstream wind power generating unit associated with the current main wind direction is in a grid-connected power generation state. If it is determined that each downstream wind turbine is in the state of grid-connected power generation, in response to the average wind direction change angle of the upstream wind turbine belonging to the current main wind direction in the first specified period being greater than the first threshold, it is determined that A second yaw deviation value of each downstream wind turbine, and a yaw control command for each downstream wind turbine associated with the current main wind direction may be generated according to the second yaw deviation.
  • each downstream wind power generating unit associated with the current main wind direction can be determined whether each downstream wind power generating unit associated with the current main wind direction is in a grid-connected power generation state. If it is determined that each downstream wind power generator is in a grid-connected power generation state, it can be determined whether the average wind speed change amount of the upstream wind power generator belonging to the current main wind direction within a second specified period is greater than a second threshold. If the average wind speed change is greater than the second threshold, it can be determined whether the pitch angle of each downstream wind turbine associated with the upstream wind turbine belonging to the current main wind direction is within a specified range. If the pitch angle is within the specified range, the minimum pitch angle of each downstream wind turbine associated with the current main wind direction can be determined, and each downstream wind power associated with the current main wind direction can be generated based on the minimum pitch angle Pitch control command for generator set.
  • each downstream wind power generator group associated with the current main wind direction may be controlled according to the control instruction.
  • control method may further include: determining whether a current operating state status of each upstream wind turbine belongs to a grid-connected state; if it is determined that a current operating state status of each upstream wind turbine belongs to a grid-connected Status, step S204 is performed.
  • the central controller 101 may control the downstream turbine to make a yaw action in accordance with the control instruction in advance according to the wind direction and wind speed information sensed by the upstream wind turbine, thereby improving power generation efficiency.
  • FIG. 3 is a functional block diagram of a control system of a wind turbine according to an embodiment of the present disclosure.
  • the control system of the wind turbine may include a data acquisition module, a data analysis module, a command push module, a timer module, a data storage module, and a group marking module.
  • the data acquisition module can collect the time stamp, wind speed, absolute wind direction, yaw position, wind direction angle, fan status, impeller speed, pitch angle and other data of the entire wind turbine in real time.
  • the sampling frequency can be a specified frequency, such as the sampling frequency It is 1Hz. It should be noted that the timestamps collected by each fan must be consistent, such as the time of the central controller.
  • the data analysis module can read the current data collected by the above data acquisition module in real time and process it with a specific algorithm in order to determine whether the current wind direction of the upstream wind turbine is one of the main wind directions of the upstream wind turbine, and the analysis also belongs to the current The working condition status of the downstream wind turbine in the main wind direction. Analyze whether the working condition of the downstream wind turbine is a small wind start, sudden wind direction or gust turbulence.
  • the data analysis module may combine the results of the association relationship between the units calculated by the group marking module to give control instructions for the downstream wind turbines associated with the current main wind direction.
  • the data storage module can meet the fast read and write performance of a large amount of data, and may include a real-time database, a relational database, and / or a file database.
  • the data storage module can store the data collected by the data acquisition module, and store the main wind direction information of the wind turbines in the entire wind farm, the information of the upstream wind turbines, and the information of the downstream wind turbines.
  • the packet marking module can read data of a certain period of time from the data storage module and perform calculation processing on the read data.
  • the reading and calculation functions performed by the group marking module do not have to be in the running state all the time, and only need to run once every certain period.
  • the timer module can call the packet marking module periodically.
  • the calling period can be no less than 1 day and no more than 30 days.
  • the command push module can use a universal protocol to achieve fast communication between the central controller (also called the wind farm controller) and the entire field wind turbine, and send control instructions to each downstream wind power generator associated with the current main wind direction. unit.
  • the controller according to the embodiment of the present disclosure may control each downstream wind turbine associated with the current main wind direction according to the obtained control instruction.
  • the above-mentioned control system of the wind turbine according to the embodiment of the present disclosure can implement a time stamp, wind speed, absolute wind direction, and yaw position of the collected wind turbine by means of a central controller (also referred to as a wind farm controller).
  • a central controller also referred to as a wind farm controller.
  • Analysis and calculation of wind direction angle, fan status, impeller speed, pitch angle and other data, as well as data interaction with the wind turbine rely on the control module in the central controller to achieve logical calculation and signal processing functions.
  • FIG. 4 is a flowchart illustrating a method for determining an association relationship between a main wind direction of a plurality of upstream wind turbines and a downstream wind turbine at the main wind direction according to an embodiment of the present disclosure.
  • step S401 the wind speed, absolute wind direction, and time stamp of each upstream wind turbine in the wind farm during the first sampling period may be obtained, and the wind speed of each upstream wind turbine in the absolute wind direction during the second sampling period may be determined.
  • the first sampling period may include a plurality of second sampling periods.
  • the first sampling period can be set to 3 months, and the second sampling period can be set to 10 minutes (that is, 10 min).
  • step S402 a plurality of sectors with a specified angle can be divided for each upstream wind turbine, and the wind frequency of each sector in the first sampling period is determined, and the predetermined number of fans with the largest wind frequency is determined.
  • the area serves as the main wind direction of the upstream wind turbine.
  • the frequency at which the average wind speed in the second sampling period in the absolute wind direction appears in the sector during the first sampling period can be determined, and this frequency is taken as the wind frequency.
  • step S403 for each main wind direction of each upstream wind turbine, it is possible to determine the cumulative startup times and each startup time of the upstream wind turbine during the first sampling period.
  • step S404 for each other wind turbine in the wind farm except for the upstream wind turbine, the cumulative start times of the other wind turbines during the first sampling time and the cumulative start of an upstream wind turbine may be determined. Whether the ratio of the number of generators reaches the ratio threshold, and whether the other wind turbine is started within a set period of time from the start-up time of the upstream wind turbine. If both determination results are positive, it may be determined in step S405 that the other wind turbine is the downstream wind turbine of the upstream wind turbine in the main wind direction. If both determination results are not positive, the process may return to step S401. For example, the cumulative start-up times of the upstream wind turbine can be set to N, and the ratio threshold can be set to 0.8.
  • the update frequency of the above-mentioned association relationship or the update frequency of internal parameters may be established only once and no longer updated, once a year, once a quarter, once a month, once every ten days, or Update once a few days and so on.
  • association relationship can also be obtained in advance through a human-computer interaction interface.
  • association relationship between each upstream wind turbine, each main wind direction of the upstream wind turbine, and the downstream wind turbine at the main wind direction may be received through a human-computer interaction interface.
  • FIG. 5 is a flowchart illustrating an operation of the group marking module in FIG. 3 according to an embodiment of the present disclosure, where the sample data of the last 3 months is taken as an example to describe the calculation processing flow performed by the group marking module.
  • the group marking module can read data such as wind speed, absolute wind direction, wind turbine status, and time stamp from the data storage module in the last 3 months, and calculate the average and maximum wind speed and / or absolute wind direction in a 10-minute period Value, minimum.
  • each upstream wind turbine a can be traversed: using 22.5 ° as a sector, calculate the wind frequency in each sector in the past 3 months (that is, the average value of the absolute wind direction within 10 minutes in the past 3 months).
  • the frequency of occurrence of each sector), and the 1 sector with the largest wind frequency or 2 sectors with the largest and 2nd largest wind frequencies are taken as the main wind direction of the upstream wind turbine a.
  • each main wind direction of each upstream wind turbine a can be traversed to find the start-up process of the unit within 3 months: when the unit starts up once, record the time; the number of start-up times is N.
  • step S504 other unit b can be traversed: if the number of startups of an upstream unit a is N, and a unit b exceeds N * 0.8 times and is started within 30 minutes after the unit a is started, the unit can be started b is marked as the downstream unit of the unit a in the main wind direction.
  • the packet marking module may output a packet marking result and store the result in the data storage module.
  • the grouping mark result may include the fan number, the main wind direction number, the downstream unit number sequence of the downstream wind turbine of each upstream wind turbine in its main wind direction.
  • Wind direction usually refers to the direction of the wind.
  • Wind direction representation methods usually include degree and azimuth representation.
  • the degree representation is the most direct way to express wind direction.
  • the direction of the wind is expressed in degrees from 0 to 360 °.
  • This representation is simple and simple. In order to more intuitively indicate the direction of the wind, you can use the azimuth representation, discretize the wind direction from 0 to 360 °, and divide the different wind direction values into corresponding sectors. Usually, 16 sectors are set, and each sector is 22.5 degrees .
  • the wind direction in the range of 348.75 ° to 360 ° and 0 to 11.25 ° is northerly, represented by N;
  • the wind direction in the range of 11.25 ° to 33.75 ° is northeast wind;
  • the wind direction in the 33.75 to 56.25 ° range is northeast wind.
  • FIG. 6 is a flowchart illustrating an operation of the data analysis module in FIG. 3 according to an embodiment of the present disclosure.
  • step S601 the current wind direction of each upstream wind turbine in the wind farm can be obtained in real time.
  • step S602 it can be determined whether the current wind direction of each upstream wind turbine belongs to the upstream wind turbine according to the association relationship between the main wind directions of the plurality of upstream wind turbines and the downstream wind turbines in the main wind direction. One of the main wind directions. If it is determined that the current wind direction of each upstream wind turbine belongs to one of the main wind directions of the upstream wind turbine, it may proceed to step S603; otherwise, continue to step S602.
  • step S603 the main wind direction to which the current wind direction belongs may be determined as the current main wind direction.
  • step S604 the downstream wind turbines associated with the current main wind direction of each upstream wind turbine may be determined according to the above-mentioned association relationship.
  • step S605 it can be determined whether the current working condition status of each upstream wind turbine belongs to the grid-connected status. If the current working condition state belongs to the grid-connected state, the process may proceed to step S606; otherwise, the process returns to step S602.
  • step S606 it can be determined whether each of the downstream wind turbines associated with the current main wind direction is in a stopped state or a standby state. If each of the downstream wind turbines is in a stopped or standby state, it can proceed to step S607; otherwise, it can proceed to step S609.
  • each downstream wind turbine unit associated with the current main wind direction may be determined according to the current wind direction of the upstream wind turbine unit belonging to the current main wind direction and the yaw position of each downstream wind turbine unit associated with the current main wind direction.
  • the first yaw bias value For example, the current wind direction of an upstream wind turbine belonging to the current main wind direction can be obtained by subtracting the yaw position of each downstream wind turbine associated with the current main wind direction to obtain the value of each downstream wind turbine associated with the current main wind direction.
  • the first yaw bias value is derived from the current wind direction of an upstream wind turbine belonging to the current main wind direction.
  • a yaw control command for each downstream wind turbine associated with the current main wind direction may be generated according to the first yaw deviation value.
  • the identification information of a downstream wind turbine associated with the current main wind direction may be carried in the yaw control command, and the yaw variable and the crew state variable in the yaw control command are set to the first yaw deviation value, respectively. And enter standby.
  • step S609 it can be determined whether the current working state status of each downstream wind power generating unit associated with the current main wind direction belongs to the grid-connected state. If the current working condition of each downstream wind turbine belongs to the grid-connected state, the process may proceed to steps S610 and S612; otherwise, no operation is performed.
  • step S610 in response to that the average wind direction change angle of the upstream wind power generating unit belonging to the current main wind direction during the first specified period is greater than the first threshold, a second yaw of each downstream wind power generating unit associated with the current main wind direction may be determined. Deviation. For example, the current absolute wind direction of the upstream wind turbine that belongs to the current main wind direction during the current first specified period may be subtracted from the average absolute wind direction of the upstream wind turbine during the first first specified period. A second yaw bias value for each associated downstream wind turbine.
  • a yaw control command for each downstream wind turbine associated with the current main wind direction may be generated according to the second yaw deviation value.
  • the identification information of a downstream wind turbine associated with the current main wind direction may be carried in the yaw control command, and the yaw variable in the yaw control command is set to the second yaw deviation value.
  • step S612 it can be determined whether the average wind speed change amount of the upstream wind power generating unit belonging to the current main wind direction in the second specified period is greater than the second threshold. If the change amount of the average wind speed is greater than the second threshold, the process may proceed to step S613; otherwise, no operation is performed.
  • the average wind speed of an upstream wind turbine belonging to the current main wind direction during the current second specified period may be subtracted from the average wind speed of the upstream wind turbine during the previous second specified period to obtain the upstream wind turbine The amount of change in the average wind speed during the second specified period, and then it is determined whether the amount of change in the average wind speed is greater than a second threshold.
  • step S613 it may be determined whether the pitch angle of each downstream wind turbine associated with the upstream wind turbine belonging to the current main wind direction is within a specified range. If the pitch angle is within the specified range, it may proceed to step S614; otherwise, no operation is performed.
  • step S614 the minimum pitch angle of each downstream wind turbine associated with the current main wind direction may be determined.
  • a pitch control command for each downstream wind turbine associated with the current main wind direction may be generated according to the minimum pitch angle.
  • the identification information of a downstream wind turbine associated with the current main wind direction may be carried in a pitch control command, and the pitch angle variable in the pitch control command is set to the minimum pitch angle.
  • the pitch control command generated for each downstream wind turbine associated with the current main wind direction may have a fixed format.
  • the pitch control command may include at least a fan number, a modified target variable name, and a target modified value, and there may be multiple modified target variables. If the unit is not in the above-mentioned target operating conditions, the control command may not be output.
  • FIG. 7 is a flowchart illustrating an operation of the data analysis module in FIG. 3 according to another embodiment of the present disclosure.
  • the data analysis module may obtain the current wind speed and absolute wind direction data of each wind turbine in the current 1 minute from the data storage module.
  • step S702 each unit can be traversed: the main wind direction sequence of the wind turbine is obtained from the data storage module.
  • step S703 it can be determined whether the average wind direction of a certain wind power generator group A in the current 1 minute belongs to one of the main wind directions. If it is determined that the average wind direction belongs to one of the main wind directions, it may proceed to step S704; otherwise, return to step S702.
  • step S704 it can be determined whether the wind turbine A belongs to a grid-connected state in the current 1 minute. If it is determined that the wind power generating unit A belongs to the grid-connected state in the current 1 minute, it may proceed to step S705; otherwise, return to step S702.
  • step S705 it can be traversed whether the downstream wind turbine B of the wind turbine A is in a shutdown or standby state. If the traversal result reflects that the downstream wind power generator B of the wind power generator set A is in a shutdown or standby state, it may proceed to step S706; otherwise, it may proceed to step S708.
  • the yaw deviation value (corresponding to the first yaw deviation value) can be obtained by subtracting the value representing the current absolute yaw position of the downstream wind turbine B from the value representing the absolute wind direction of the wind turbine A.
  • the yaw deviation value can be expressed as "value 1: dev_a”.
  • a pitch control command for a downstream wind turbine associated with the main wind direction may be output, and identification information indicating the small wind start of the downstream wind turbine is carried in the pitch control command.
  • the pitch control command may include: fan number: B; variable 1: yaw; value 1: dev_a; variable 2: fan status; value 2: enter standby. This indicates that the working condition of the downstream wind turbine at this time is small wind start, and it will enter the standby state.
  • step S708 it can be determined whether the downstream fan B is in the state of grid-connected power generation. If it is determined that the downstream fan B is in the state of grid-connected power generation, the process may proceed to steps S709 and S710; otherwise, no operation is performed.
  • step S709 it can be determined whether the change in the wind direction of the upstream wind turbine A in the last 1 minute from the wind direction of the previous 1 minute is greater than 20 degrees. If it is determined that the change is greater than 20 degrees, it may proceed to step S711; otherwise, no operation is performed.
  • the yaw deviation value (equivalent to the second yaw deviation value) can be obtained by subtracting the average absolute wind direction within the last 1 minute from the average absolute wind direction within the last 1 minute of the wind turbine A, and the yaw deviation The value can be expressed as "dev_b".
  • a pitch control command for a downstream wind turbine associated with the main wind direction may be output, and identification information indicating a sudden wind direction change of the downstream wind turbine is carried in the pitch control command.
  • the pitch control command may include: fan number: B; variable 1: yaw action; value 1: dev_b. This indicates that the working condition of the downstream wind turbine at this time is a sudden change in wind direction, and a yaw action will be performed.
  • step S710 it can be determined whether the wind speed within the last 10s of the upstream wind turbine A has increased by 5m / s relative to the wind speed within the last 10s. If it is determined that the wind speed increases by 5 m / s, the process may proceed to step S713; otherwise, no operation is performed.
  • step S713 it can be determined whether the pitch angle of the downstream fan B is within a range of 0 degrees ⁇ 2 degrees. If it is determined that the pitch angle is within the range of 0 degrees ⁇ 2 degrees, the process may proceed to step S714; otherwise, no operation is performed.
  • step S714 the minimum pitch angle of each downstream wind power unit associated with the current main wind direction may be determined, and a pitch control command for each downstream wind power unit associated with the current main wind direction may be generated according to the minimum pitch angle. .
  • a pitch control command for a downstream wind turbine associated with the main wind direction may be output, and identification information indicating gust turbulence of the downstream wind turbine may be carried in the pitch control command.
  • the pitch control command may include: fan number: B; variable 1: minimum pitch angle; value 1: 3 degrees. This indicates that the working condition of the downstream wind turbine at this time is gust turbulence, and yaw action will be performed.
  • an embodiment of the present disclosure further provides a control device for a wind turbine.
  • control device 1011 of the wind power generator set may include a current wind direction determination module 10111, a main wind direction determination module 10112, a downstream wind power generator determination module 10113, and a control instruction determination module 10114.
  • the current wind direction determination module 10111 can obtain the current wind direction of each upstream wind turbine in the wind farm in real time.
  • the main wind direction determination module 10112 may determine the current main wind direction to which the current wind direction of each upstream wind power generator set obtained by the current wind direction determination module 10111 in real time belongs.
  • the downstream wind turbine determining module 10113 may determine the associated current wind direction of each upstream wind turbine according to the association relationship between the main wind directions of the multiple upstream wind turbines and the downstream wind turbines in the main wind direction. Downstream wind turbine.
  • the control instruction determination module 10114 may determine a control instruction for each of the downstream wind turbines associated with the current main wind direction according to the working condition state and the operation parameter of the downstream wind turbines associated with the current main wind direction.
  • control device 1011 may be integrated in the central controller 101 of the wind farm.
  • an embodiment of the present disclosure further provides a controller of a wind turbine.
  • the controller 1021 of the wind turbine may include a receiving module 10211 and a control module 10212.
  • the controller 1021 may be communicatively connected with the control device 1011 of the wind turbine described with reference to FIG. 8.
  • the receiving module 10211 may receive a control instruction sent by the control device 1011 for each downstream wind turbine associated with the current main wind direction.
  • the control module 10212 may control each downstream wind turbine associated with the current main wind direction according to the control instruction received by the receiving module 10211.
  • the controller 1021 may be integrated in the main controller 102 of the wind turbine.
  • the present disclosure also provides a computer-readable storage medium for storing a computer program that, when executed by a processor, can implement a method for controlling a wind turbine according to an embodiment of the present disclosure. .
  • control system for a wind turbine.
  • the control system may include: the above-mentioned control device of the wind turbine; and the above-mentioned controller of the wind turbine connected in communication with the control device.
  • the embodiment of the present disclosure can predict the wind speed and direction for the downstream wind turbine, start the small wind in advance, and control the downstream turbine to make a yaw action in advance after the downstream wind turbine starts generating power.
  • wind turbines usually use wind speed and direction data collected by their own sensors as the basis for wind yaw, and it often takes a delay of about 20 minutes to determine the wind direction. If the direction of the incoming wind and the yaw position of the wind turbine are large, it will take several minutes to complete the yaw-to-wind action, which will require a delay of about 30 minutes before the start.
  • the central controller can control the downstream wind turbine at The yaw action is completed before the wind arrives, which adds about 30 minutes to the power generation time of the wind turbine, which significantly improves the power generation and efficiency of the wind turbine.
  • steps in the flowchart of the drawings are sequentially displayed according to the directions of the arrows, these steps are not necessarily performed in the order indicated by the arrows. Unless explicitly stated herein, the execution of these steps is not strictly limited, and they can be performed in other orders. Moreover, at least a part of the steps in the flowchart of the drawing may include multiple sub-steps or stages. These sub-steps or stages may not necessarily be executed at the same time, but may be executed at different times, and their execution order is not necessarily Performed sequentially, but may be performed in turn or alternately with other steps or at least a part of the sub-steps or stages of other steps.

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Abstract

一种风力发电机组的控制方法，该控制方法包括：实时获取风电场内每个上游风力发电机组的当前风向；确定每个上游风力发电机组的当前风向所属的当前主风向；根据多个上游风力发电机组的主风向和在主风向的下游风力发电机组之间的关联关系，确定每个上游风力发电机组的当前主风向所关联的下游风力发电机组；根据该当前主风向所关联的下游风力发电机组的工况状态和工况参数，确定针对该当前主风向所关联的每个下游风力发电机组的控制指令；根据该控制指令，对该当前主风向所关联的每个下游风力发电机组进行控制。还涉及相应的控制装置、控制器及控制系统。

Description

风力发电机组的控制方法、控制装置、控制器及控制系统 技术领域
本公开涉及风力发电技术，具体而言，本公开涉及一种风力发电机组的控制方法、控制装置、控制器及控制系统。
背景技术
随着风力发电机组的规模逐渐扩大和机组安全保护日趋完善，风力发电机组的发电量、发电效率等技术指标日益受到关注。风力发电机组对风向变化情况的响应速度，直接影响着风力发电机组的发电量和发电效率。
通常，风力发电机组无法有效地预先判断出环境变化并做出快速响应。当全场的风力发电机组处于停机状态时，若风速开始变大，则每台风机单独进行对作用于自身的风速的判断。若在连续的一段时间内风速高于设定阈值，则开始对风偏航动作，并进入待机状态。
当全场的风力发电机组处于正常发电状态时，若风向产生较大变化，则每台风机基于自身传感器采集的风速和风向数据单独进行对风的判断。若在连续的一段时间内对风的偏差高于设定阈值，则风力发电机组开始对风偏航动作以继续发电状态。然而，这种情况下，风力发电机组对环境变化的响应比较慢，从每台风机单独进行对风的判断，到开始对风偏航动作，往往需要较长时间，从而造成发电量损失。
例如，当全场的风力发电机组处于正常发电状态时，若突然出现较强湍流风，则风力发电机组不能迅速做出反应，只能被动承受风机载荷冲击，从而造成发电量损失。
发明内容
根据本公开的实施例，提供了一种风力发电机组的控制方法，该控制方法包括：
实时获取风电场内每个上游风力发电机组的当前风向；
确定每个上游风力发电机组的当前风向所属的当前主风向；
根据预先获得的多个上游风力发电机组的主风向和在主风向的下游风力发电机组之间的关联关系，确定每个上游风力发电机组的当前主风向所关联的下游风力发电机组；
根据该当前主风向所关联的下游风力发电机组的工况状态和工况参数，确定针对该当前主风向所关联的每个下游风力发电机组的控制指令；
根据该控制指令，对该当前主风向所关联的每个下游风力发电机组进行控制。
根据本公开的实施例，提供了一种风力发电机组的控制装置，该控制装置包括：
当前风向确定模块，用于实时获取风电场内每个上游风力发电机组的当前风向；
主风向确定模块，用于确定每个上游风力发电机组的当前风向所属的当前主风向；
下游风力发电机组确定模块，用于根据预先获得的多个上游风力发电机组的主风向和在主风向的下游风力发电机组之间的关联关系，确定每个上游风力发电机组的当前主风向所关联的下游风力发电机组；
控制指令确定模块，用于根据该当前主风向所关联的下游风力发电机组的工况状态和工况参数，确定针对该当前主风向所关联的每个下游风力发电机组的控制指令。
根据本公开的实施例，提供了一种风力发电机组的控制器，该控制器与上述的控制装置通信连接，该控制器包括：接收模块，用于接收该控制装置发送的针对当前主风向所关联的每个下游风力发电机组的控制指令；控制模块，用于根据该接收模块接收到的控制指令，对该当前主风向所关联的每个下游风力发电机组进行控制。
根据本公开的实施例，提供了一种风力发电机组的控制系统，该控制系统包括：上述的控制装置；以及上述的控制器，所述控制器与所述控制装置通信连接。
根据本公开的实施例，提供了一种计算机可读的存储介质，该计算机可读的存储介质用于存储计算机程序，该计算机程序被处理器执行时实现上述的风力发电机组的控制方法。
本公开的实施例可以利用风力发电机组的控制装置，通过控制算法感知上游风力发电机组的风力风向，提前控制下游风力发电机组预偏航对风，从而使得下游风力发电机组能提前做出响应动作，可以有效地减小发电量损失，提高发电效率。
附图说明
本公开的上述和/或附加的方面和优点从下面结合附图对实施例的描述中将变得明显和容易理解，在附图中：
图1为根据本公开的实施例的风力发电机组的控制系统的框图；
图2为例示根据本公开的实施例的风力发电机组的控制方法的流程图；
图3为根据本公开的实施例的风力发电机组的控制系统的功能框图；
图4为例示根据本公开的实施例的用于确定多个上游风力发电机组的主风向和在主风向的下游风力发电机组之间的关联关系的方法的流程图；
图5为例示根据本公开的实施例的图3中的分组标记模块的操作的流程图；
图6为例示根据本公开的实施例的图3中的数据分析模块的操作的流程图；
图7为例示根据本公开的另一实施例的图3中的数据分析模块的操作的流程图；
图8为根据本公开的实施例的风力发电机组的控制装置的框图；以及
图9为根据本公开的实施例的风力发电机组的控制器的框图。
具体实施方式
下面详细描述本公开的实施例，一些示例在附图中示出，其中自始至终相同或类似的标号表示相同或类似的元件或具有相同或类似功能的元 件。下面通过参考附图描述的实施例仅是示例性的，不能被视为对本公开的限制。
本技术领域技术人员可以理解，除非另外定义，这里使用的所有术语(包括技术术语和科学术语)具有与本公开所属领域中的普通技术人员的一般理解相同的意义。还应该理解的是，除非被特定定义，诸如通用字典中定义的那些术语应该被理解为具有与相关技术的上下文中的意义一致的意义，而不应该用理想化或过于正式的含义来解释。
下面首先介绍本公开涉及的一些技术术语。
上风向和下风向：风先吹到的位置称为上风向位置，风后吹到的位置称为下风向位置。上风向也可以被理解为风吹来的方向。自然界中的风通常是由上风向吹向下风向的。
上游风力发电机组：位于上风向的风力发电机组。
下游风力发电机组：位于下风向的风力发电机组。
接下来，结合附图详细描述本公开的实施例。
图1为根据本公开的实施例的风力发电机组的控制系统10的框图。如图1所示，控制系统10可以包括：风电场的中央控制器101和风力发电机组的主控器102。主控器102可以包括风力发电机组的控制器1021。中央控制器101可以包括风力发电机组的控制装置1011。控制装置1011与控制器1021可以通信连接。
图2为例示根据本公开的实施例的风力发电机组的控制方法的流程图。
在步骤S201，可以实时获取(例如，通过传感器)风电场内每个上游风力发电机组的当前风向。
在步骤S202，可以确定每个上游风力发电机组的当前风向所属的当前主风向。例如，可以根据预先获得的多个上游风力发电机组的主风向和在主风向的下游风力发电机组之间的关联关系，确定每个上游风力发电机组的当前风向是否属于该上游风力发电机组的主风向之一。若确定该上游风力发电机组的当前风向属于该上游风力发电机组的主风向之一，则可以将当前风向所属的主风向确定为当前主风向。
在步骤S203，可以根据上述关联关系，确定每个上游风力发电机组的当前主风向所关联的下游风力发电机组。
在步骤S204，可以根据当前主风向所关联的下游风力发电机组的工况状态和工况参数(包括但不限于时间戳、风速、绝对风向、偏航位置、风向角、风机状态、叶轮转速、桨距角等)，确定针对当前主风向所关联的每个下游风力发电机组的控制指令。
例如，可以确定当前主风向所关联的每个下游风力发电机组是否处于停机状态或待机状态。如果确定每个下游风力发电机组处于停机状态或待机状态，则可以根据属于当前主风向的上游风力发电机组的当前风向、以及当前主风向所关联的每个下游风力发电机组的偏航位置，确定当前主风向所关联的每个下游风力发电机组的第一偏航偏差值，并且可以根据第一偏航偏差值，生成针对当前主风向所关联的每个下游风力发电机组的偏航控制命令。
又例如，可以确定当前主风向所关联的每个下游风力发电机组是否处于并网发电状态。如果确定每个下游风力发电机组处于并网发电状态，则可以响应于属于当前主风向的上游风力发电机组在第一指定时段内的平均风向变化角度大于第一阈值，确定当前主风向所关联的每个下游风力发电机组的第二偏航偏差值，并且可以根据第二偏航偏差值，生成针对当前主风向所关联的每个下游风力发电机组的偏航控制命令。
再例如，可以确定当前主风向所关联的每个下游风力发电机组是否处于并网发电状态。如果确定每个下游风力发电机组处于并网发电状态，则可以确定属于当前主风向的上游风力发电机组在第二指定时段内的平均风速变化量是否大于第二阈值。若平均风速变化量大于第二阈值，则可以确定属于当前主风向的上游风力发电机组所关联的每个下游风力发电机组的桨距角是否在指定范围内。若桨距角在指定范围内，则可以确定当前主风向所关联的每个下游风力发电机组的最小桨距角，并且可以根据最小桨距角，生成针对当前主风向所关联的每个下游风力发电机组的变桨控制命令。
在步骤S205，可以根据控制指令，对当前主风向所关联的每个下游风力发电机组进行控制。
此外，根据本公开的实施例，该控制方法还可以包括：确定每个上游风力发电机组的当前工况状态是否属于并网状态；若确定每个上游风力发电机组的当前工况状态属于并网状态，则执行上述步骤S204。
如上所述，在下游风力发电机组开始发电后，中央控制器101可以依据上游风力发电机组感知到的风向和风速信息，提前控制下游机组按照控制指令做出偏航动作，从而提高发电效率。
图3为根据本公开的实施例的风力发电机组的控制系统的功能框图。
根据本公开的实施例的风力发电机组的控制系统可以包括数据采集模块、数据分析模块、命令推送模块、计时器模块、数据存储模块和分组标记模块。
数据采集模块可以实时采集全场风力发电机组的时间戳、风速、绝对风向、偏航位置、风向角、风机状态、叶轮转速、桨距角等数据，采样频率可以为指定的频率，例如采样频率为1Hz。需要说明的是，各台风机采集到的时间戳需要保持一致，如统一以中央控制器的时间为准。
数据分析模块可以实时读取上述数据采集模块采集到的当前数据，以特定算法进行处理，以便判断上游风力发电机组的当前风向是否为该上游风力发电机组的主风向之一，且分析同属于当前主风向的下游风力发电机组的工况状态，分析下游风力发电机组的工况状态是否属于小风启机、风向突变或阵风湍流。数据分析模块可以结合分组标记模块计算出的机组间关联关系的结果，给出针对当前主风向所关联的下游风力发电机组的控制指令。
数据存储模块可以满足大量数据的快速读写性能，可以包含实时数据库、关系型数据库和/或文件数据库等。该数据存储模块可以存储由上述数据采集模块采集到的数据，存储全风场的风力发电机组的主风向信息、上游风力发电机组的信息、下游风力发电机组的信息等。
分组标记模块可以从上述数据存储模块中读取一定时间周期的数据，并对所读取的数据进行计算处理。分组标记模块所执行的读取与计算功能不必一直处于运行状态，每间隔一定周期运行一次即可。
计时器模块可以定时调用分组标记模块。例如，调用周期可以不少于 1天且不大与30天。
命令推送模块可以采用通用协议，实现中央控制器(也称为风电场控制器)与全场风力发电机组之间的快速通信，将控制指令下发到当前主风向所关联的每个下游风力发电机组。根据本公开的实施例的控制器可以根据得到的控制指令，对当前主风向所关联的每个下游风力发电机组进行控制。
根据本公开的实施例的风力发电机组的上述控制系统可以借助中央控制器(也称为风电场控制器)，实现对所采集到的风力发电机组的时间戳、风速、绝对风向、偏航位置、风向角、风机状态、叶轮转速、桨距角等数据的分析计算以及与风力发电机组的数据交互，依托中央控制器中的控制模块实现逻辑计算和信号处理功能。
图4为例示根据本公开的实施例的用于确定多个上游风力发电机组的主风向和在主风向的下游风力发电机组之间的关联关系的方法的流程图。
在步骤S401，可以获取风电场内每个上游风力发电机组在第一取样时段内的风速、绝对风向和时间戳，并确定每个上游风力发电机组在绝对风向上在第二取样时段内的风速平均值、风速最大值和风速最小值。具体地，第一取样时段可以包括多个第二取样时段。例如，可以设定第一取样时段为3个月，设定第二取样时段为10分钟(即10min)。
在步骤S402，可以为每个上游风力发电机组划分出多个具有指定夹角的扇区，确定每个扇区在第一取样时段内的风频，并将风频最大的预定个数的扇区作为该上游风力发电机组的主风向。例如，对于每个上游风力发电机组的每个扇区，可以确定在绝对风向上在第二取样时间段内的平均风速在第一取样时段内在该扇区出现的频率，并将该频率作为风频。例如，可以计算在绝对风向上在10min内的平均风速，并计算每个扇区近3个月内的风频。
在步骤S403，对于每个上游风力发电机组的每个主风向，可以确定该上游风力发电机组在第一取样时段内的累计启机次数和每次启机时刻。
在步骤S404，对于风电场中除了上游风力发电机组之外的每个其它风力发电机组，可以确定该其它风力发电机组在第一取样时间内的累计启机 次数与一个上游风力发电机组的累计启机次数的比例是否达到比例阈值，且该其它风力发电机组是否在自该上游风力发电机组的启机时刻起的设定时段内启机。若两个确定结果都是肯定的，则可以在步骤S405确定该其它风力发电机组为该上游风力发电机组在该主风向的下游风力发电机组。若两个确定结果不都是肯定的，则可以返回到步骤S401。例如，可以设定上游风力发电机组的累计启机次数为N，设定该比例阈值为0.8。
由此，可以建立每个上游风力发电机组、该上游风力发电机组的每个主风向和在该主风向的下游风力发电机组之间的关联关系。
根据本公开的实施例，上述关联关系的更新频率或者内部参数的更新频率可以为只建立一次而不再更新、一年更新一次、一个季度更新一次、一个月更新一次、十几天更新一次或几天更新一次等。
此外，上述关联关系还可以通过人机交互界面来预先获得。具体地，可以通过人机交互界面，接收每个上游风力发电机组、该上游风力发电机组的每个主风向和在该主风向的下游风力发电机组之间的关联关系。
图5为例示根据本公开的实施例的图3中的分组标记模块的操作的流程图，其中以最近3个月的样本数据为例，描述分组标记模块执行的计算处理流程。
在步骤S501，分组标记模块可以从数据存储模块读取最近3个月的风速、绝对风向、风机状态、时间戳等数据，并计算10min时间段内的风速和/或绝对风向的平均值、最大值、最小值。
在步骤S502，可以遍历每台上游风力发电机组a：以22.5°为一个扇区，计算每个扇区近3个月内的风频(即，绝对风向在10min内的平均值近3个月内在每个扇区出现的频率)，并将风频最大的1个扇区或者风频分别为最大和第二大的2个扇区作为该上游风力发电机组a的主风向。
在步骤S503，可以遍历每台上游风力发电机组a的每个主风向，寻找机组3个月内的启机过程：当机组发生一次启机时，记录该时刻；累加其启机次数为N。
在步骤S504，可以遍历其他机组b：若一台上游机组a的启机次数为N，而某台机组b超过N*0.8次在机组a启机后的30min内启机，则可以将 该机组b标记为该机组a在该主风向的下游机组。
在步骤S505，分组标记模块可以输出分组标记结果并将该结果存入数据存储模块。分组标记结果可以包括每台上游风力发电机组在其主风向上的下游风力发电机组的风机号、主风向号、下游机组编号序列等。
下面说明上述的用扇区表示风向的由来。
风向通常指风的来向。风向表示方法通常包括度数表示法和方位表示法。度数表示法是最直接的风向表示方法，用0～360°度数表示风的来向，这种表示方法通俗简单。为了更加直观的表示风的来向，可以采用方位表示，把0～360°的风向离散化，把不同风向值划分到相应的扇区，通常设16个扇区，每22.5度为一个扇区。例如，348.75°～360°和0～11.25°区间的风向为北风，以N表示；11.25°～33.75°区间的风向为北东北风；33.75～56.25°区间的风向为东北风。
图6为例示根据本公开的实施例的图3中的数据分析模块的操作的流程图。
在步骤S601，可以实时获取风电场内每个上游风力发电机组的当前风向。
在步骤S602，可以根据预先获得的多个上游风力发电机组的主风向和在主风向的下游风力发电机组之间的关联关系，确定每个上游风力发电机组的当前风向是否属于该上游风力发电机组的主风向之一。若确定每个上游风力发电机组的当前风向属于该上游风力发电机组的主风向之一，则可以进到步骤S603；否则，继续执行步骤S602。
在步骤S603，可以将当前风向所属的主风向确定为当前主风向。
在步骤S604，可以根据上述关联关系，确定每个上游风力发电机组的当前主风向所关联的下游风力发电机组。
在步骤S605，可以确定每个上游风力发电机组的当前工况状态是否属于并网状态。若当前工况状态属于并网状态，则可以进到步骤S606；否则，返回到步骤S602。
在步骤S606，可以确定当前主风向所关联的每个下游风力发电机组是否处于停机状态或待机状态。若每个下游风力发电机组处于停机状态或待 机状态，则可以进到步骤S607；否则，可以进到步骤S609。
在步骤S607，可以根据属于当前主风向的上游风力发电机组的当前风向、以及当前主风向所关联的每个下游风力发电机组的偏航位置，确定当前主风向所关联的每个下游风力发电机组的第一偏航偏差值。例如，可以通过将属于当前主风向的上游风力发电机组的当前风向减去当前主风向所关联的每个下游风力发电机组的偏航位置，得到当前主风向所关联的每个下游风力发电机组的第一偏航偏差值。
在步骤S608，可以根据第一偏航偏差值，生成针对当前主风向所关联的每个下游风力发电机组的偏航控制命令。例如，可以将当前主风向所关联的一个下游风力发电机组的标识信息携带于偏航控制命令中，并且将偏航控制命令中的偏航变量和机组状态变量分别设置为第一偏航偏差值和进入待机状态。
在步骤S609，可以确定当前主风向所关联的每个下游风力发电机组的当前工况状态是否属于并网状态。若每个下游风力发电机组的当前工况状态属于并网状态，则可以进到步骤S610和S612；否则，不进行操作。
在步骤S610，可以响应于属于当前主风向的上游风力发电机组在第一指定时段内的平均风向变化角度大于第一阈值，确定当前主风向所关联的每个下游风力发电机组的第二偏航偏差值。例如，可以通过将属于当前主风向的上游风力发电机组在当前第一指定时段内的平均绝对风向减去该上游风力发电机组在上一个第一指定时段内的平均绝对风向，得到当前主风向所关联的每个下游风力发电机组的第二偏航偏差值。
在步骤S611，可以根据第二偏航偏差值，生成针对当前主风向所关联的每个下游风力发电机组的偏航控制命令。例如，可以将当前主风向所关联的一个下游风力发电机组的标识信息携带于偏航控制命令中，并且将偏航控制命令中的偏航变量设置为第二偏航偏差值。
在步骤S612，可以确定属于当前主风向的上游风力发电机组在第二指定时段内的平均风速变化量是否大于第二阈值。若该平均风速变化量大于第二阈值，则可以进到步骤S613；否则，不进行操作。
例如，可以通过将属于当前主风向的上游风力发电机组在当前第二指 定时段内的平均风速减去该上游风力发电机组在上一个第二指定时段内的平均风速，得到该上游风力发电机组在第二指定时段内的平均风速变化量，进而确定该平均风速变化量是否大于第二阈值。
在步骤S613，可以确定属于当前主风向的上游风力发电机组所关联的每个下游风力发电机组的桨距角是否在指定范围内。若该桨距角在指定范围内，则可以进到步骤S614；否则，不进行操作。
在步骤S614，可以确定当前主风向所关联的每个下游风力发电机组的最小桨距角。
在步骤S615，可以根据最小桨距角，生成针对当前主风向所关联的每个下游风力发电机组的变桨控制命令。例如，可以将当前主风向所关联的一个下游风力发电机组的标识信息携带于变桨控制命令中，并且将该变桨控制命令中的桨距角变量设置为该最小桨距角。
根据本公开的实施例，为了便于风力发电机组接收并执行命令，为当前主风向所关联的每个下游风力发电机组生成的的变桨控制命令可以具有固定的格式。例如，该变桨控制命令可以至少包含风机编号、修改目标变量名称、目标修改值，其中可以存在多个修改目标变量。若机组不处于上述的目标工况，则可以不输出控制命令。
图7为例示根据本公开的另一实施例的图3中的数据分析模块的操作的流程图。
在步骤S701，数据分析模块可以从数据存储模块获取各台风力发电机组在当前1分钟的风速、绝对风向数据。
在步骤S702，可以遍历各台机组：从数据存储模块获取该风力发电机组的主风向序列。
在步骤S703，可以判断某一台风力发电机组A在当前1分钟的平均风向是否属于主风向之一。若判断出该平均风向属于主风向之一，则可以进到步骤S704；否则，返回到步骤S702。
在步骤S704，可以判断该风力发电机组A在当前1分钟是否属于并网状态。若判断出该风力发电机组A在当前1分钟属于并网状态，则可以进到步骤S705；否则，返回到步骤S702。
在步骤S705，可以遍历该风力发电机组A的下游风力发电机组B是否处于停机或待机状态。若遍历结果反映出该风力发电机组A的下游风力发电机B是处于停机或待机状态，则可以进到步骤S706；否则，可以进到步骤S708。
在步骤S706，可以通过将表征风力发电机组A的绝对风向的值减去表征下游风机B的当前绝对偏航位置的值，获得偏航偏差值(相当于第一偏航偏差值)。在生成的具有固定格式的变桨控制命令中，偏航偏差值可以以“数值1：dev_a”表示。
在步骤S707，可以输出针对主风向所关联的一个下游风力发电机组的变桨控制命令，并将该下游风力发电机组的表示小风启机的标识信息携带于该变桨控制命令中。该变桨控制命令可以包含：风机号：B；变量1：偏航；数值1：dev_a；变量2：风机状态；数值2：进入待机。这表明此时的下游风力发电机组的工况状态为小风启机，将进入待机状态。
在步骤S708，可以判断下游风机B是否处于并网发电状态。若判断出下游风机B是处于并网发电状态，则可以进到步骤S709和S710；否则，不作操作。
在步骤S709，可以判断上游风力发电机组A最近1min的风向相对于上个1min的风向的变化是否大于20度。若判断出该变化大于20度，则可以进到步骤S711；否则，不进行操作。
在步骤S711，可以通过将风力发电机组A最近1min内的平均绝对风向减去其上个1min内的平均绝对风向，获得偏航偏差值(相当于第二偏航偏差值)，该偏航偏差值可以以“dev_b”表示。
在步骤S712，可以输出针对主风向所关联的一个下游风力发电机组的变桨控制命令，并将该下游风力发电机组的表示风向突变的标识信息携带于该变桨控制命令中。该变桨控制命令可以包含：风机号：B；变量1：偏航动作；数值1：dev_b。这表明此时的下游风力发电机组的工况状态为风向突变，将执行偏航动作。
在步骤S710，可以判断上游风力发电机组A最近10s内的风速相对于上个10s内的风速是否增大5m/s。若判断出所述风速增大5m/s，则可以进到步骤S713；否则，不进行操作。
在步骤S713，可以判断下游风机B的桨距角是否在0度±2度范围内。若判断出该桨距角在0度±2度范围内，则可以进到步骤S714；否则，不进行操作。
在步骤S714，可以确定当前主风向所关联的每个下游风力发电机组的最小桨距角，并根据最小桨距角来生成针对当前主风向所关联的每个下游风力发电机组的变桨控制命令。此外，可以输出针对主风向所关联的一个下游风力发电机组的变桨控制命令，并将该下游风力发电机组的表示阵风湍流的标识信息携带于该变桨控制命令中。该变桨控制命令可以包含：风机号：B；变量1：最小桨距角；数值1：3度。这表明此时的下游风力发电机组的工况状态为阵风湍流，将执行偏航动作。
基于同一发明构思，本公开的实施例还提供一种风力发电机组的控制装置。
参见图8，风力发电机组的控制装置1011可以包括当前风向确定模块10111、主风向确定模块10112、下游风力发电机组确定模块10113和控制指令确定模块10114。
当前风向确定模块10111可以实时获取风电场内每个上游风力发电机组的当前风向。
主风向确定模块10112可以确定当前风向确定模块10111实时获取的每个上游风力发电机组的当前风向所属的当前主风向。
下游风力发电机组确定模块10113可以根据预先获得的多个上游风力发电机组的主风向和在主风向的下游风力发电机组之间的关联关系，确定每个上游风力发电机组的当前主风向所关联的下游风力发电机组。
控制指令确定模块10114可以根据当前主风向所关联的下游风力发电机组的工况状态和工况参数，确定针对当前主风向所关联的每个下游风力发电机组的控制指令。
可选地，参见图1，控制装置1011可以被集成设置在风电场的中央控制器101中。
基于同一发明构思，本公开的实施例还提供一种风力发电机组的控制器。
参见图9，风力发电机组的控制器1021可以包括接收模块10211和控制模块10212。控制器1021可以与参照图8描述的风力发电机组的控制装置1011通信连接。
接收模块10211可以接收控制装置1011发送的针对当前主风向所关联的每个下游风力发电机组的控制指令。
控制模块10212可以根据接收模块10211接收到的控制指令，对当前主风向所关联的每个下游风力发电机组进行控制。
可选地，参见图1，控制器1021可以被集成设置在风力发电机组的主控器102中。
基于同一发明构思，本公开还提供一种计算机可读的存储介质，该存储介质用于存储计算机程序，该计算机程序被处理器执行时可以实现根据本公开的实施例的风力发电机组的控制方法。
基于同一发明构思，本公开还提供一种风力发电机组的控制系统，该控制系统可以包括：上述的风力发电机组的控制装置；以及上述的与该控制装置通信连接的风力发电机组的控制器。
如上所述，本公开的实施例可以为下游风力发电机组预测风速风向，提前对小风启机，并且可以在下游风力发电机组开始发电后，提前控制下游机组做出偏航动作。例如，通常风力发电机组以自身传感器采集的风速风向数据作为对风偏航的依据，往往需要延迟20分钟左右才能判断风向。若来风方向与风力发电机组停机偏航位置偏差较大，则还需要数分钟才能完成偏航对风动作，从而累计需要延迟约30分钟后才能开始启机。相比之下，以矩阵型风场中风机间隔600米、上游风力发电机组感测到起风时风速5m/s为例，根据本公开的实施例的中央控制器可控制下游风力发电机组在风到来前完成偏航动作，使风力发电机组增加约30分钟发电时间，显著提高了风力发电机组的发电量和发电效率。
应该理解的是，虽然附图的流程图中的各个步骤按照箭头的指示依次显示，但是这些步骤并不必然按照箭头指示的顺序依次执行。除非本文中有明确的说明，这些步骤的执行并没有严格的顺序限制，其可以以其他的顺序执行。而且，附图的流程图中的至少一部分步骤可以包括多个子步骤 或者多个阶段，这些子步骤或者阶段并不必然在同一时刻执行，而可以在不同的时刻执行，其执行顺序也不必然是依次进行，而是可以与其他步骤或者其他步骤的子步骤或者阶段的至少一部分轮流或者交替地执行。
以上所述仅是本公开的部分实施方式。应当指出，对于本技术领域的普通技术人员来说，在不脱离本公开的原理的前提下，还可以做出若干变型和润饰，这些变型和润饰也应被视为在本公开的范围内。

Claims (17)

  1. 一种风力发电机组的控制方法，包括以下步骤：
    实时获取风电场内每个上游风力发电机组的当前风向；
    确定每个所述上游风力发电机组的当前风向所属的当前主风向；
    根据预先获得的多个上游风力发电机组的主风向和在主风向的下游风力发电机组之间的关联关系，确定每个所述上游风力发电机组的当前主风向所关联的下游风力发电机组；
    根据所述当前主风向所关联的下游风力发电机组的工况状态和工况参数，确定针对所述当前主风向所关联的每个下游风力发电机组的控制指令；
    根据所述控制指令，对所述当前主风向所关联的每个下游风力发电机组进行控制。
  2. 根据权利要求1所述的控制方法，其中，确定所述当前主风向的步骤包括：
    根据所述关联关系，确定每个所述上游风力发电机组的当前风向是否属于该上游风力发电机组的主风向之一；
    如果确定所述当前风向属于该上游风力发电机组的主风向之一，则将所述当前风向所属的主风向确定为所述当前主风向。
  3. 根据权利要求1所述的控制方法，其中，确定所述控制指令的步骤包括：
    确定所述当前主风向所关联的每个下游风力发电机组是否处于停机状态或待机状态；
    如果所述每个下游风力发电机组处于停机状态或待机状态，则根据属于所述当前主风向的上游风力发电机组的当前风向、以及所述当前主风向所关联的每个下游风力发电机组的偏航位置，确定所述当前主风向所关联的每个下游风力发电机组的第一偏航偏差值；
    根据所述第一偏航偏差值，生成针对所述当前主风向所关联的每个下 游风力发电机组的偏航控制命令。
  4. 根据权利要求3所述的控制方法，其中，
    通过将属于所述当前主风向的上游风力发电机组的当前风向减去所述当前主风向所关联的每个下游风力发电机组的偏航位置，得到所述第一偏航偏差值；
    将所述当前主风向所关联的一个下游风力发电机组的标识信息携带于所述偏航控制命令中，并将所述偏航控制命令中的偏航变量和机组状态变量分别设置为所述第一偏航偏差值和进入待机状态。
  5. 根据权利要求1所述的控制方法，其中，确定所述控制指令的步骤包括：
    确定所述当前主风向所关联的每个下游风力发电机组是否处于并网发电状态；
    如果所述每个下游风力发电机组处于并网发电状态，则响应于属于所述当前主风向的上游风力发电机组在第一指定时段内的平均风向变化角度大于第一阈值，确定所述当前主风向所关联的每个下游风力发电机组的第二偏航偏差值；
    根据所述第二偏航偏差值，生成针对所述当前主风向所关联的每个下游风力发电机组的偏航控制命令。
  6. 根据权利要求5所述的控制方法，其中，
    通过将属于所述当前主风向的上游风力发电机组在当前第一指定时段内的平均绝对风向减去该上游风力发电机组在上一个第一指定时段内的平均绝对风向，得到所述当前主风向所关联的每个下游风力发电机组的第二偏航偏差值；
    将所述当前主风向所关联的一个下游风力发电机组的标识信息携带于所述偏航控制命令中，并将所述偏航控制命令中的偏航变量设置为所述第二偏航偏差值。
  7. 根据权利要求1所述的控制方法，其中，确定所述控制指令的步骤包括：
    确定所述当前主风向所关联的每个下游风力发电机组是否处于并网发电状态；
    如果所述每个下游风力发电机组处于并网发电状态，则确定属于所述当前主风向的上游风力发电机组在第二指定时段内的平均风速变化量是否大于第二阈值；
    如果所述平均风速变化量大于第二阈值，则确定属于所述当前主风向的上游风力发电机组所关联的每个下游风力发电机组的桨距角是否在指定范围内；
    如果所述桨距角在指定范围内，则确定所述当前主风向所关联的每个下游风力发电机组的最小桨距角；
    根据所述最小桨距角，生成针对所述当前主风向所关联的每个下游风力发电机组的变桨控制命令。
  8. 根据权利要求7所述的控制方法，其中，
    通过将属于所述当前主风向的上游风力发电机组在当前第二指定时段内的平均风速减去该上游风力发电机组在上一个第二指定时段内的平均风速，得到所述平均风速变化量，进而确定所述平均风速变化量是否大于所述第二阈值；
    将所述当前主风向所关联的一个下游风力发电机组的标识信息携带于所述变桨控制命令中，并将所述变桨控制命令中的桨距角变量设置为所述最小桨距角。
  9. 根据权利要求1所述的控制方法，还包括：
    确定每个所述上游风力发电机组的当前工况状态是否属于并网状态；
    如果所述当前工况状态属于并网状态，则执行确定所述控制指令的步骤。
  10. 根据权利要求1所述的控制方法，其中，所述关联关系是通过下列操作确定的：
    获取风电场内每个上游风力发电机组在第一取样时段内的风速、绝对风向和时间戳，并确定每个上游风力发电机组在绝对风向上在第二取样时段内的风速平均值、风速最大值和风速最小值，第一取样时段包括多个第二取样时段；
    为每个上游风力发电机组划分出多个具有指定夹角的扇区，确定每个扇区在第一取样时段内的风频，并将风频最大的预定个数的扇区作为该上游风力发电机组的主风向；
    对于每个上游风力发电机组的每个主风向，确定该上游风力发电机组在第一取样时段内的累计启机次数和每次启机时刻；
    对于所述风电场中除了上游风力发电机组之外的每个其它风力发电机组，确定该其它风力发电机组在第一取样时间内的累计启机次数与一个上游风力发电机组的所述累计启机次数的比例是否达到比例阈值，且该其它风力发电机组是否在自该上游风力发电机组的启机时刻起的设定时段内启机，若两个确定结果都是肯定的，则确定该其它风力发电机组为该上游风力发电机组在该主风向的下游风力发电机组；
    建立每个上游风力发电机组、该上游风力发电机组的每个主风向和在该主风向的下游风力发电机组之间的关联关系。
  11. 根据权利要求10所述的控制方法，其中，
    对于每个上游风力发电机组的每个扇区，确定在所述绝对风向上在第二取样时间段内的平均风速在第一取样时段内在该扇区出现的频率，并将该频率作为所述风频。
  12. 一种风力发电机组的控制装置，包括：
    当前风向确定模块，用于实时获取风电场内每个上游风力发电机组的当前风向；
    主风向确定模块，用于确定每个所述上游风力发电机组的当前风向所 属的当前主风向；
    下游风力发电机组确定模块，用于根据预先获得的多个上游风力发电机组的主风向和在主风向的下游风力发电机组之间的关联关系，确定每个所述上游风力发电机组的当前主风向所关联的下游风力发电机组；
    控制指令确定模块，用于根据所述当前主风向所关联的下游风力发电机组的工况状态和工况参数，确定针对所述当前主风向所关联的每个下游风力发电机组的控制指令。
  13. 根据权利要求12所述的控制装置，其被集成设置在风电场的中央控制器中。
  14. 一种风力发电机组的控制器，与根据权利要求12或13所述的控制装置通信连接，所述控制器包括：
    接收模块，用于接收所述控制装置发送的针对当前主风向所关联的每个下游风力发电机组的控制指令；
    控制模块，用于根据所述接收模块接收到的控制指令，对所述当前主风向所关联的每个下游风力发电机组进行控制。
  15. 根据权利要求14所述的控制器，其被集成设置在风力发电机组的主控器中。
  16. 一种风力发电机组的控制系统，包括：
    根据权利要求12或13所述的控制装置；以及
    根据权利要求14或15所述的控制器，所述控制器与所述控制装置通信连接。
  17. 一种计算机可读的存储介质，用于存储计算机程序，该计算机程序被处理器执行时实现根据权利要求1-11中任一项所述的控制方法。
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