[go: up one dir, main page]

WO2026008115A1 - Étalonnage d'un capteur d'une éolienne - Google Patents

Étalonnage d'un capteur d'une éolienne

Info

Publication number
WO2026008115A1
WO2026008115A1 PCT/DK2025/050112 DK2025050112W WO2026008115A1 WO 2026008115 A1 WO2026008115 A1 WO 2026008115A1 DK 2025050112 W DK2025050112 W DK 2025050112W WO 2026008115 A1 WO2026008115 A1 WO 2026008115A1
Authority
WO
WIPO (PCT)
Prior art keywords
wind turbine
parameter
wake
wind
measured
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Pending
Application number
PCT/DK2025/050112
Other languages
English (en)
Inventor
Johnny Nielsen
Goncalo Artur Duarte Pereira
Poul Brandt Christensen
Mahmood MIRZAEI
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Vestas Wind Systems AS
Original Assignee
Vestas Wind Systems AS
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Vestas Wind Systems AS filed Critical Vestas Wind Systems AS
Publication of WO2026008115A1 publication Critical patent/WO2026008115A1/fr
Pending legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Classifications

    • 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
    • F03D7/049—Automatic control; Regulation by means of an electrical or electronic controller controlling wind farms in relation to the wake effect
    • 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
    • F03D7/04—Automatic control; Regulation
    • F03D7/042—Automatic control; Regulation by means of an electrical or electronic controller
    • F03D7/043—Automatic control; Regulation by means of an electrical or electronic controller characterised by the type of control logic
    • F03D7/046—Automatic control; Regulation by means of an electrical or electronic controller characterised by the type of control logic with learning or adaptive control, e.g. self-tuning, fuzzy logic or neural network
    • 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
    • F05B2270/10—Purpose of the control system
    • F05B2270/20—Purpose of the control system to optimise the performance of a machine
    • F05B2270/204—Purpose of the control system to optimise the performance of a machine taking into account the wake effect
    • 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
    • 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
    • F05B2270/328—Blade pitch angle
    • 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
    • F05B2270/331—Mechanical loads

Definitions

  • the invention relates to calibrating a sensor of a wind turbine.
  • the invention relates to calibrating the wind turbine sensor using parameter values obtained when the wind turbine is not experiencing wake flow.
  • Wind turbines are used to capture energy in the wind as it flows past them, and to generate electrical power from the captured energy, e.g. to be supplied to an electrical grid. Wind turbines operate in a variety of conditions, e.g. environmental conditions, and monitoring and controlling operational parameters of a wind turbine in view of such conditions is important for maximising power production and/or minimising wind turbine component loading.
  • An increasing number of the functions implemented by wind turbines used to control wind turbine operation can automatically adapt the parameters associated therewith to be optimised for the respective wind turbine being controlled.
  • a wind turbine function is a function that has the aim of determining a relative wind direction for which a wind turbine is maximising power production, and then adjusting the relative wind direction to where it is measured as zero degrees.
  • a wind turbine function that calibrates measured wind speed in different wind speed bins based on a difference between measured wind speed and estimated wind speed in each respective wind speed bin.
  • control functions of wind turbines also perform control actions based on measured values of parameters associated with a wind turbine, such as a wind parameter, e.g. wind direction or wind speed.
  • a wind parameter e.g. wind direction or wind speed.
  • an ice detection function may compare estimated wind speed against measured wind speed to detect when ice has formed on rotor blades of a wind turbine. Wind turbine efficiency generally decreases when ice is present, and so control actions to remove ice may be implemented when ice is detected.
  • aspects of the present invention reside in an appreciation that measured parameters of a wind turbine - and, in particular, a relationship between measured parameters and other (monitored) parameters of the wind turbine - are influenced by wake flow experienced by the wind turbine. Examples of the invention therefore take this into account for wind turbine functions that perform calibrations I detections based on measured and monitored parameters.
  • a method of calibrating a sensor of a wind turbine comprises obtaining over time a sensor signal, from the sensor, indicative of values of a measured parameter associated with the wind turbine.
  • the method comprises obtaining over time a monitored signal indicative of values of a monitored operational parameter associated with the wind turbine.
  • the method comprises obtaining over time a wake detection signal indicating a wake flow experienced by the wind turbine.
  • the method comprises, based on the sensor signal, the monitored signal and the wake detection signal, identifying the measured parameter values and the monitored operational parameter values obtained when the wind turbine is not experiencing wake flow.
  • the method comprises, based on the identified values of the measured parameter and the identified values of the monitored operational parameter, determining over time a calculated operational parameter associated with the wind turbine as a function of the measured parameter.
  • the method comprises determining a correction to the measured parameter based on the calculated operational parameter.
  • the method comprises adjusting the measured parameter based on the correction to calibrate the sensor.
  • the method may comprise, in an implementation phase after a calibration phase in which the sensor is calibrated: determining a value of a control parameter of the wind turbine based on the adjusted measured parameter; and controlling the wind turbine in accordance with the control parameter value.
  • the method may comprise, in the implementation phase: obtaining the wake detection signal indicating the wake flow experienced by the wind turbine; and, based on the wake detection signal, controlling the wind turbine in accordance with the control parameter value only when the wind turbine is not experiencing wake flow.
  • the method may comprise, in the implementation phase: determining a further value of the control parameter of the wind turbine; and based on the wake detection signal, controlling the wind turbine in accordance with the further value of the control parameter when the wind turbine is experiencing wake flow.
  • the method may comprise, in the calibration phase, and based on the sensor signal, the monitored signal and the wake detection signal, identifying the measured parameter values and monitored operational parameter values obtained when the wind turbine is experiencing wake flow.
  • the method may comprise, in the calibration phase, and based on the identified values of the measured parameter and identified values of the monitored operational parameter when the wind turbine is experiencing wake flow, determining over time a further calculated operational parameter associated with the wind turbine as a function of the measured parameter.
  • the method may comprise, in the calibration phase, determining a further correction to the measured parameter based on the further calculated operational parameter.
  • the further value of the control parameter of the wind turbine may be determined based on the measured parameter adjusted according to the determined further correction.
  • the wake flow signal may include an indication of a type of wake flow being experienced by the wind turbine from a plurality of defined wake flow types.
  • the method may comprise one or more of the following steps for each defined wake flow type.
  • the method may comprise, based on the sensor signal, the monitored signal and the wake detection signal, identifying the measured parameter values and monitored operational parameter values obtained when the wind turbine is experiencing the respective defined wake flow type.
  • the method may comprise, based on the identified values of the measured parameter and identified values of the monitored operational parameter when the wind turbine is experiencing the respective defined wake flow type, determining over time a respective wake type-specific calculated operational parameter associated with the wind turbine as a function of the wake parameter.
  • the method may comprise determining a respective wake type-specific correction to the measured parameter based on the respective wake type-specific calculated operational parameter.
  • the method may comprise determining a respective wake flow-specific value of the control parameter of the wind turbine based on the measured parameter adjusted according to the determined respective wake type-specific correction.
  • the method may comprise, based on the wake detection signal, controlling the wind turbine in accordance with the respective wake flow-specific value of the control parameter when the wind turbine is experiencing the respective defined wake flow type.
  • the plurality of defined wake flow types may include one or more of: full wake flow; half wake flow; left-hand wake flow; and right-hand wake flow.
  • the sensor may be a wind sensor.
  • the sensor may be a wind direction sensor.
  • the measured parameter may be a wind direction relative to the wind turbine.
  • the monitored operational parameter may be pitch angle of at least one rotor blade of the wind turbine.
  • the calculated operational parameter may be a statistical representation of the obtained pitch angle values.
  • the monitored operational parameter may be a wind power parameter of the wind turbine.
  • the calculated operational parameter may be a statistical representation of the obtained wind power values.
  • the wind power parameter may be one of a rotor power, a grid power, a torque and a rotor blade loading, of the wind turbine.
  • the control parameter may be a yaw angle for the wind turbine.
  • the sensor may be a wind speed sensor.
  • the measured parameter may be measured wind speed.
  • the monitored operational parameter may be estimated wind speed in the vicinity of the wind turbine.
  • the calculated operational parameter may be an error parameter indicative of a difference between measured and estimated wind speed.
  • the control parameter may be one or more of: a rotor blade pitch control parameter; a torque control parameter; and an ice detection control parameter.
  • a non-transitory, computer readable storage medium storing instructions thereon that, when executed by one or more computer processors, causes the one or more computer processors to perform the method defined above.
  • a controller for a wind turbine configured to obtain over time a sensor signal, from a sensor of the wind turbine, indicative of values of a measured parameter associated with wind flow in the vicinity of the wind turbine.
  • the controller is configured to obtain over time a monitored signal indicative of values of a monitored operational parameter associated with the wind turbine.
  • the controller is configured to obtain over time a wake detection signal indicating a wake flow experienced by the wind turbine.
  • the controller is configured to, based on the sensor signal, the monitored signal and the wake detection signal, identify the measured parameter values and monitored operational parameter values obtained when the wind turbine is not experiencing wake flow.
  • the controller is configured to, based on the identified values of the measured parameter and identified values of the monitored operational parameter, determine over time a calculated operational parameter associated with the wind turbine as a function of the measured parameter.
  • the controller is configured to determine a correction to the measured parameter based on the calculated operational parameter.
  • the controller is configured to adjust the measured parameter based on the correction.
  • a wind turbine comprising a controller as defined above.
  • Figure 1 schematically illustrates a wind turbine in accordance with an aspect of the invention
  • Figure 2 schematically illustrates a wind farm comprising a plurality of wind turbines, including the wind turbine of Figure 1 ;
  • Figure 3(a) shows a plot of output power against relative wind direction of the wind turbine of Figure 1 for data collected over a period of time
  • Figure 3(b) shows a plot of output power against relative wind direction of the wind turbine of Figure 1 for data collected over the period of time where the data collected when the wind turbine is experiencing wake flow is removed;
  • Figure 4 shows the steps of a method, performed by a controller of the wind turbine of Figure 1 , in accordance with an aspect of the invention.
  • FIG. 1 illustrates, in a schematic view, an example of a wind turbine 10.
  • the wind turbine 10 includes a tower 102, a nacelle 103 disposed at the apex of, or atop, the tower 102, and a rotor 104 operatively coupled to a generator housed inside the nacelle 103.
  • the nacelle 103 houses other components required for converting wind energy into electrical energy, e.g. a gearbox, and various components needed to operate, control, and optimise the performance of the wind turbine 10.
  • the rotor 104 of the wind turbine 10 includes a central hub 105 and three rotor blades 106 that project outwardly from the central hub 105.
  • the wind turbine 10 includes a number of sensors for measuring various parameters, e.g. wind parameters, associated with wind turbine operation.
  • the wind turbine 10 may include one or more wind direction sensors for measuring incoming wind direction in the vicinity of the wind turbine 10.
  • the wind direction sensor(s) may be a wind vane or any other suitable type of sensor, and may be located on the rotor 104 or nacelle 103 of the wind turbine, for instance.
  • the wind turbine 10 may include one or more wind speed sensors for measuring wind speed in the vicinity of the wind turbine 10.
  • the wind speed sensor(s) may be an anemometer, for instance.
  • the wind speed sensor may similarly be located on the rotor 104 or nacelle 103, and may be part of a single device that also comprises the wind direction sensor.
  • an accelerometer e.g. for measuring vibrations (fore-aft and/or side-side) of the tower 102.
  • One or more accelerometers may be placed at the top of the tower 102 or in/on the nacelle 103.
  • a further type of sensor that may be provided is a blade load sensor.
  • blade load sensors may be placed at, or in the vicinity of, a root end of each blade 106 in a manner such that the sensor detects loading in the blade 106.
  • loading may be detected in the flap (flapwise) direction (in/out of plane) or in the edge (edgewise) direction (in-plane).
  • Such sensors may be displacement sensors, strain gauge sensors or optical Bragg-sensors, for instance.
  • the wind turbine 10 includes a control system or controller (not shown in Figure 1).
  • the controller may be placed inside the nacelle, in the tower or distributed at a number of locations inside (or externally to) the turbine 10 and communicatively connected to one another.
  • the wind turbine controller performs various functions for controlling operation of the wind turbine 10.
  • the control signals output by the controller - to control wind turbine components, such as pitch of the rotor blades 106 and speed of the wind turbine generator - may be determined on input signals received by the controller, e.g. measurement signals obtained from sensors such as the sensors outlined above.
  • wind turbine controller One example of a function performed by the wind turbine controller is a wind direction adjustment function.
  • wind turbine power production is maximised when the wind turbine 10 faces directly into the incoming wind, i.e. when the wind turbine rotor 104 is controlled to be aligned with the incoming wind (by adjusting the yaw angle of the wind turbine using a yaw drive mechanism).
  • wind direction sensors of the wind turbine 10 may suffer from inaccuracies, e.g. because of the rotor 104 disrupting the wind flow prior to it being measured by the sensor.
  • the aim of the wind direction adjustment function is to determine the relative wind direction that maximises power production of the wind turbine 10 and then to adjust I calibrate the wind direction sensor measuring the relative direction such that the relative wind direction that maximises power production corresponds to zero degrees.
  • This is an example of a wind turbine function that calibrates a sensor, namely, a wind direction sensor, based on measured and monitored parameters associated with the wind turbine.
  • the wind direction adjustment function may be performed differently in dependence on whether the wind turbine 10 is in full load operation or partial load operation.
  • EP3394434A1 describes an approach for wind direction adjustment during full load operation, in which the maximum power for a given wind direction is set based on the determined maximum pitch angle observed for the given wind direction.
  • EP3394435A1 describes an approach for wind direction adjustment during partial load operation, in which correlation with maximum power for a given wind direction may be performed directly.
  • a wind speed adjustment function in form of an adaptive correction function which, over time, calibrates measured wind speed - as measured by a wind speed sensor of the wind turbine 10 - in different defined wind speed bins I ranges based on a difference between measured and estimated wind speed in the respective wind speed bin.
  • Such wind speed adjustment is therefore another example of a wind turbine function that calibrates a sensor, namely, a wind speed sensor, based on measured and monitored parameters associated with the wind turbine.
  • An approach for performing such The wind speed adjustment is described in EP3478962A1.
  • the estimated wind speed is determined based on a wind speed estimator which used measured power and wind speed.
  • a further example of a function performed by the wind turbine controller is an ice detection function which detects when ice forms on the rotor blades 106 or other components of the wind turbine 10.
  • Wind turbine efficiency e.g. power production
  • the wind turbine controller may therefore instruct control actions to remove the ice, e.g. blade heating.
  • the presence of ice on the blades can also cause a safety issue, e.g. a risk of ice being thrown from the blades as they rotate about the rotor 104, and so wind turbine operation may need to be halted when ice is detected.
  • An ice detection function may determine a Rotor Efficiency Loss (REL) caused by ice.
  • REL Rotor Efficiency Loss
  • the ice detection function may perform a comparison of estimated and measured wind speeds and, in particular, a decrease in estimated wind speed against measured wind speed. If the decrease is greater than a threshold value then a determination that ice is present may be performed.
  • ice detection is therefore another example of a function in which an accurate measurement of wind speed is needed.
  • the wind turbine 10 may be part of a wind farm or wind park.
  • Figure 2 shows a wind park 20 that includes a plurality of wind turbines 21 , including the wind turbine 10 of Figure 1 , in a defined geographical area.
  • the wind park 20 may be an onshore or offshore wind farm.
  • Each wind turbine 21 may be controlled to balance maximising the captured energy I power production of the turbine against (minimising) the loading experienced by one or more components of the turbine 21 .
  • Figure 2 schematically illustrates a direction 22 of wind flow in the wind park 20.
  • wake is generated downstream of the wind turbine 21a. This means that wind flow downstream of the wind turbine 21a is perturbed or disturbed relative to upstream of the wind turbine 21a, resulting in a reduction in the speed of the wind flow and/or an increase in the turbulence of the wind flow.
  • the wind flow past one or more of the other wind turbines may include wake effects caused by the wind flow past the first wind turbine 21a.
  • the wind turbine 10 may experience wake flow caused I generated by the first wind turbine 21a as it is downstream of the first wind turbine 21a.
  • Wake flow experienced by the wind turbine 10 may additionally or alternatively be caused I generated by factors other than neighbouring wind turbines.
  • wake flow may be generated as wind flows over/round a building or other object, or by geographical features such as hills and valleys.
  • accurate calibrations I detections may be achieved when the wind turbine 10 is operating when the wind turbine 10 is not experiencing wake flow generated by neighbouring wind turbines or other objects I features. That is, wake flow can contribute to inaccurate calibrations of sensors being performed, inaccurate detections being determined, etc.
  • wind turbine functions may perform with reduced accuracy as it is common for wind turbines to operate in wake flow at least some of the time. For instance, a wind turbine that operates in the middle of a wind farm may experience wake flow up to 50% of its operating time.
  • the present invention is advantageous in that it provides for more accurate calibrations of wind turbine sensors to be used with one or more wind turbine functions (such as those outlined above). In turn, this means that more accurate detections I determinations based on sensor measurements may be obtained, which further means that improved control of the wind turbine may be implemented, e.g. increased power production. This is achieved by taking into account wake flow experienced by the wind turbine when calibrating a sensor for use with one or more wind turbine functions. In examples of the invention, only parameter values, e.g. measured parameter values obtained using wind turbine sensors, obtained when the wind turbine is not experiencing wake flow, i.e. when the wind turbine is experiencing free stream flow, are used to calibrate the sensor(s). Further beneficial effects of the invention will become apparent from the following description.
  • Figure 3(a) is a plot 31 of output power (grid power) of the wind turbine 10 as a function of relative wind direction, where values of the output power and relative wind direction have been obtained over a period of time.
  • the period of time during which the data is collected is a period of time in which the wind turbine 10 experiences wake flow for a relatively significant amount of the time, e.g. up to 50% of the time.
  • the wind turbine 10 should produce the most output power when the relative wind direction is 0 degrees, i.e. when the wind turbine rotor 104 is aligned with the wind.
  • the calibrated sensor would have an error of either about 3.5 or about 7.5 degrees, depending on whether the raw data 31 or the fitted data curve 33 was used for the calibration.
  • Figure 3(b) is a plot 35 of output power (grid power) of the wind turbine 10 as a function of relative wind direction, where values of the output power and relative wind direction have been obtained over a period of time.
  • the collected data included in the plot 35 only includes data collected when the wind turbine 10 was not experiencing wake flow. This is performed via the use of a wake flow signal that indicates whether the wind turbine 10 is experiencing wake flow or not. When the wake flow signal indicates that the wind turbine 10 is in wake then the obtained power output and relative wind direction data is discarded (i.e. not included in the plot of Figure 3(b)).
  • the obtained power output and relative wind direction data is included in the plot of Figure 3(b). It may be seen in Figure 3(b) that the output power in the collected data 35 is maximised at about 0 degrees (indicated by the line 36). It is further seen that a fitted curve 37 of the collected data is maximised at about 0 degrees.
  • Figure 4 shows the steps of a method 40 performed by a controller of the wind turbine 10 in accordance with examples of the invention.
  • the method is for calibrating a sensor of the wind turbine 10.
  • the method 40 involves obtaining over time a sensor signal, from the sensor, indicative of values of a measured parameter associated with the wind turbine 10.
  • the measured parameter may be any suitable parameter associated with wind turbine operation.
  • the measured parameter may be a wind parameter.
  • the measured wind parameter may be wind direction as measured by a wind direction sensor of the wind turbine 10.
  • the measured wind parameter may be wind speed as measured by a wind speed sensor of the wind turbine 10.
  • the measured parameter may be wind turbine tower acceleration, rotor blade loading, or any other suitable parameter.
  • the measured parameter values may be obtained over any suitable period of time during which the wind turbine is operational, e.g. a number of days, weeks or months.
  • the measured parameter values may be obtained at any suitable intervals of time, e.g. at each sampling point of the wind turbine controller or at less frequent intervals such as every few minutes (e.g. every ten minutes).
  • the method 40 involves obtaining over time a monitored signal indicative of values of a monitored operational parameter associated with the wind turbine 10.
  • the monitored operational parameter may be any suitable parameter associated with wind turbine operation.
  • the monitored operational parameter may be a wind power parameter of the wind turbine 10, such as an output power, a grid power, a rotor power, a torque of the wind turbine 10, a rotor loading of the wind turbine 10, etc.
  • the output power may be a measured or estimated value, e.g. determined using a defined equation for power as a function of a defined coefficient of power and wind speed.
  • the monitored operational parameter may be an estimated wind speed in the vicinity of the wind turbine 10.
  • Estimated wind speed may be obtained in any suitable manner, such as based on a power of the wind turbine or on wind turbine thrust, as is known in the art.
  • the monitored operational parameter may be a rotor pitch angle of one or more rotor blades 106 of the wind turbine 10.
  • the monitored pitch angle may for instance be a pitch angle reference output by a controller, e.g. full load controller, of the wind turbine 10.
  • the monitored operational parameter values may be obtained I sampled at the same time points I intervals as the measured parameter values (such that pairs of corresponding values of the measured parameter and monitored operational parameter are obtained).
  • the method 40 involves obtaining over time a wake detection signal indicating a wake flow experienced by the wind turbine 10.
  • the wake detection signal may be a signal that indicates whether the wind turbine 10 is currently experiencing wake flow (of any type) or currently experiencing no wake flow, i.e. a binary signal.
  • the wake detection signal may indicate a type of wake flow being experienced by the wind turbine 10 (if the wind turbine is experiencing wake). For instance, the wake detection signal may indicate whether the wind turbine 10 is in full wake or half wake conditions. In full wake conditions, the wind flow past the turbine 10 across a full span of the swept area of the rotor 104 is wake flow.
  • the wake detection signal may further indicate the type of half wake flow, e.g. lefthand wake or right-hand wake, indicating whether the wake flow is at a left or right hand side of the turbine rotor 104.
  • the type of wake flow indicated in the wake detection signal may further indicate a severity of the wake flow being experienced by the wind turbine 10.
  • the wake detection signal may be received from a wake detection module of the wind turbine controller, or may be received from off-board the wind turbine 10.
  • the wake detection signal may be received at each time step I interval that the measured parameter values and monitored operational parameter values are obtained.
  • the method 40 may involve a step of determining wake flow experienced by the wind turbine 10, and then generating the wake detection signal based on the determination.
  • the determination of wake flow may be performed in any suitable manner. For instance, this could be based on a temporal variation of measured wind speed in the vicinity of the wind turbine 10 or based on power production I output for certain measured wind speeds.
  • the method 40 involves identifying the measured parameter values (step 401) and the monitored operational parameter values (step 402) obtained when the wind turbine 10 is not experiencing wake flow. This identification is performed with respect to the received wake detection signal (step 403) that indicates the wake flow being experienced by the wind turbine 10.
  • the wake detection signal indicates that the wind turbine 10 is not experiencing wake flow
  • values of the measured parameter and monitored operational parameter obtained during that time are retained (i.e. the ‘identified’ values).
  • the wake detection signal indicates that the wind turbine 10 is experiencing wake flow
  • values of the measured parameter and monitored operational parameter obtained during that time are discarded or ignored. In this way, only parameter values obtained when the wind turbine 10 is experiencing no wake flow are retained for the following calibration steps.
  • the method 40 involves determining over time a calculated operational parameter associated with the wind turbine 10 as a function of the measured parameter. In particular, this determination is performed based on the identified values of the monitored operational parameter, i.e. the values of the monitored operational parameter obtained when the wind turbine 10 was in a no wake condition.
  • the calculated operational parameter may be any suitable parameter to be used to calibrate the wind turbine sensor. For instance, when the monitored operational parameter is a wind power parameter, the calculated operational parameter may be a statistical representation of the obtained wind power values.
  • output power values are collected over time and then a statistical representation of the collected values in the form of average values for each relative wind direction (or range of wind directions) is determined, as shown in the plot 35 in Figure 3(b).
  • the average output power values may be the calculated operational parameter values.
  • Other types of statistical representations may be used as calculated operational parameters in different contexts, e.g. variation, standard deviation, etc.
  • the monitored operational parameter is rotor blade pitch angle of the rotor blades 106
  • the calculated operational parameter may be a statistical representation of the obtained pitch angle values.
  • the calculated operational parameter may be an error parameter indicative of a difference between measured and estimated wind speed. This may be the case in the wind speed adjustment function mentioned above.
  • the method 40 involves determining a correction to the measured parameter based on the calculated operational parameter.
  • This correction may in some examples be in the form of an offset. For instance, in the wind direction adjustment example described above, it is determined for what relative wind direction the maximum output power is achieved using the plotted data (i.e. using the calculated operational parameter), and then an offset is determined such that the maximum output power is shifted to a relative wind direction of 0 degrees. Indeed, the measured parameter - in this case, the relative wind direction - is adjusted based on the correction I offset to calibrate the sensor.
  • the correction may be in a form other than an offset, e.g. a gain I multiple.
  • Steps 401 to 406 may be regarded as a calibration phase or training phase of the method 40. Further steps of the method 40 may be regarded as an implementation phase or execution phase, which make use of the calibration performed during the calibration phase to control the wind turbine 10. For instance, once the wind turbine sensor has been calibrated, in an implementation phase the method 40 may involve determining a value of a control parameter of the wind turbine 10 based on the adjusted measured parameter, controlling the wind turbine 10 in accordance with the control parameter value.
  • the control parameter may be any suitable parameter for controlling operation of the wind turbine 10.
  • the control parameter may be a yaw angle for the wind turbine 10.
  • the wind turbine 10 may be controlled to be aligned with the incoming wind direction, and the adjusted relative wind direction, obtained using the calibrated wind direction sensor, may be used to control the yaw angle so that the relative wind direction is 0 degrees.
  • the control parameter may be a rotor blade pitch control parameter, e.g. for controlling blade pitch angle to maximise power production (in full load).
  • the control parameter may be a torque control parameter, e.g. to limit loading on the wind turbine rotor 104.
  • the control parameter may alternatively be an ice detection control parameter.
  • the wind turbine controller may output a control signal to initiate heating of the blades or to shut down the wind turbine 10.
  • phase control of the wind turbine based on measurements from the calibrated sensor is performed irrespective of whether the wind turbine 10 is operating in wake flow conditions or not (despite the sensor having been calibrated based on data obtained in no wake flow conditions). Even having the sensor calibrated correctly for no wake conditions provides a significant increase in wind turbine performance.
  • control of the wind turbine is additionally based on the wake detection signal, i.e. additionally based on the flow conditions being experienced by the turbine 10 during operation.
  • the method 40 may involve obtaining the wake detection signal indicating the wake flow experienced by the wind turbine 10 and, based on the wake detection signal, controlling the wind turbine in accordance with the control parameter value only when the wind turbine is not experiencing wake flow.
  • control of the wind turbine 10 when the wake detection signal indicates that the wind turbine 10 is in wake flow conditions may be performed in different ways.
  • a further I different value of the control parameter may be determined and used to control the wind turbine when the wind turbine 10 is experiencing wake flow.
  • the further value of the control parameter may for instance be a default value.
  • the sensor in the calibration phase the sensor is calibrated based on parameter data collected during no wake flow conditions and the calibrated sensor is then used in an implementation is no wake flow and/or wake flow conditions. This could be regarded as disabling certain wind turbine functions, when the wind turbine is experiencing wake flow, or not training the wind turbine sensor I function when the wind turbine is in wake flow.
  • a further I different I separate calibration of the sensor may be performed based on parameter data collected when the wind turbine 10 is experiencing wake flow. This separate calibration may be used for controlling the wind turbine 10 in the implementation phase when the wind turbine 10 is experiencing wake flow.
  • a single further I separate calibration or correction may be determined that is to be applied for wake flow of any type, or separate calibrations I corrections may be performed for each of a plurality of defined types of wake flow, such as full wake, left-hand only wake, right-hand only wake, wake severity above a certain level, etc.
  • the described method may be applied to various other functions of a wind turbine.
  • the method may be applied to one or more of a tilt-yaw controller, an upwind yaw controller and a converter controller.
  • a controller of the wind turbine 10 for performing the described method may be in the form of any suitable computing device, for instance one or more functional units or modules implemented on one or more computer processors. Such functional units may be provided by suitable software running on any suitable computing substrate using conventional or custom processors and memory. The one or more functional units may use a common computing substrate (for example, they may run on the same server) or separate substrates, or one or both may themselves be distributed between multiple computing devices.
  • a computer memory may store instructions for performing the methods performed by the controller, and the processor(s) may execute the stored instructions to perform the method.
  • the controller may be located in one or more locations of the wind turbine 10, e.g. in the wind turbine tower 102.

Landscapes

  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • Sustainable Development (AREA)
  • Sustainable Energy (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Artificial Intelligence (AREA)
  • Evolutionary Computation (AREA)
  • Fuzzy Systems (AREA)
  • Mathematical Physics (AREA)
  • Software Systems (AREA)
  • Wind Motors (AREA)

Abstract

L'invention concerne l'étalonnage d'un capteur d'éolienne. L'invention consiste à obtenir au cours du temps un signal de capteur, provenant du capteur, indiquant des valeurs de paramètre mesurées associées à l'éolienne ; à obtenir dans le temps un signal surveillé indiquant des valeurs de paramètre opérationnel surveillées associées à l'éolienne ; et à obtenir au cours du temps un signal de détection de sillage indiquant un flux de sillage subi par l'éolienne. Sur la base des signaux de détection de capteur, surveillés et de sillage, l'invention consiste à identifier les valeurs de paramètre opérationnel surveillées mesurées obtenues lorsque l'éolienne ne subit pas de flux de sillage. Sur la base des valeurs identifiées des paramètres opérationnels mesurés et surveillés, l'invention consiste à déterminer dans le temps un paramètre opérationnel calculé en fonction du paramètre mesuré, à déterminer une correction du paramètre mesuré sur la base du paramètre opérationnel calculé, et à ajuster le paramètre mesuré sur la base de la correction pour étalonner le capteur.
PCT/DK2025/050112 2024-07-04 2025-07-02 Étalonnage d'un capteur d'une éolienne Pending WO2026008115A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
DKPA202430386 2024-07-04
DKPA202430386 2024-07-04

Publications (1)

Publication Number Publication Date
WO2026008115A1 true WO2026008115A1 (fr) 2026-01-08

Family

ID=96431144

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/DK2025/050112 Pending WO2026008115A1 (fr) 2024-07-04 2025-07-02 Étalonnage d'un capteur d'une éolienne

Country Status (1)

Country Link
WO (1) WO2026008115A1 (fr)

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP3394435A1 (fr) 2015-12-23 2018-10-31 Vestas Wind Systems A/S Procédé de commande pour une turbine éolienne
EP3394434A1 (fr) 2015-12-23 2018-10-31 Vestas Wind Systems A/S Procédé de commande pour une éolienne
EP3478962A1 (fr) 2016-06-30 2019-05-08 Vestas Wind Systems A/S Procédé de commande pour une éolienne
WO2023025365A1 (fr) 2021-08-25 2023-03-02 Vestas Wind Systems A/S Identification de perturbations de vent à écoulement libre récurrentes associées à une éolienne
US20230272775A1 (en) * 2021-06-25 2023-08-31 WindESCo, Inc. Systems and methods of coordinated yaw control of multiple wind turbines
US20240200536A1 (en) * 2021-04-27 2024-06-20 Siemens Gamesa Renewable Energy A/S Monitoring of wind direction measurements in wind parks

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP3394435A1 (fr) 2015-12-23 2018-10-31 Vestas Wind Systems A/S Procédé de commande pour une turbine éolienne
EP3394434A1 (fr) 2015-12-23 2018-10-31 Vestas Wind Systems A/S Procédé de commande pour une éolienne
EP3478962A1 (fr) 2016-06-30 2019-05-08 Vestas Wind Systems A/S Procédé de commande pour une éolienne
US20240200536A1 (en) * 2021-04-27 2024-06-20 Siemens Gamesa Renewable Energy A/S Monitoring of wind direction measurements in wind parks
US20230272775A1 (en) * 2021-06-25 2023-08-31 WindESCo, Inc. Systems and methods of coordinated yaw control of multiple wind turbines
WO2023025365A1 (fr) 2021-08-25 2023-03-02 Vestas Wind Systems A/S Identification de perturbations de vent à écoulement libre récurrentes associées à une éolienne

Similar Documents

Publication Publication Date Title
US11111903B2 (en) Yaw auto-calibration for a wind turbine generator
TWI788290B (zh) 風力渦輪機偏航失準估測
EP2588755B1 (fr) Etalonnage de capteur d'éolienne
CN102648345B (zh) 风力涡轮机的控制方法
DK2112373T3 (en) Process for operating a wind power plant
US10036692B2 (en) System and method for estimating rotor blade loads of a wind turbine
EP3225837B1 (fr) Procédé et dispositif d'étalonnage en continu d'une mesure de direction de vent
US10487804B2 (en) Systems and methods for validating wind farm performance improvements
US11181096B2 (en) Control method for a wind turbine
DK2515122T3 (en) Method for measuring wind direction just after a wind turbine rotor
US20120230820A1 (en) Method and arrangement for detecting a blade pitch angle unbalance of a rotor blade system of a wind turbine
US10641244B2 (en) Adaptive control of a wind turbine by detecting a change in performance
US9874198B2 (en) Method of operating a wind turbine
CN108474348B (zh) 用于风力涡轮机的控制方法
US10119521B2 (en) Estimating and controlling loading experienced in a structure
US11098698B2 (en) System and method for auto-calibrating a load sensor system of a wind turbine
EP3643914B1 (fr) Système et procédé pour protéger des éoliennes contre les charges extrêmes et de fatigue
WO2019007579A1 (fr) Détermination d'une valeur de vitesse du vent
US9920744B2 (en) System and method for detecting rotor asymmetry
WO2012069843A1 (fr) Pales de rotor de turbine éolienne
WO2026008115A1 (fr) Étalonnage d'un capteur d'une éolienne
EP4430298B1 (fr) Procédé et dispositif d'étalonnage d'un système de lacet d'une éolienne
EP4547958B1 (fr) Commande de perte de sillage d'éolienne à l'aide d'une perte de sillage aval détectée en fonction de la direction du vent
US20250382944A1 (en) Wind turbine wake loss control using detected downstream wake loss severity