Patent Description:
Wind turbine control technology is used for optimisation of power and minimisation of loads. Many different loads act on a wind turbine, such as aerodynamic, gravity, centrifugal and inertial loads. Changes in the loads experienced by a wind turbine may be caused by wind conditions in the vicinity of the wind turbine, e.g. wind shear or turbulence, or may be caused by changing operation of the wind turbine, e.g. grid loss.

It is known that wind turbines generate sound or noise from different sources, e.g. mechanical sources such as drivetrain tonality, and aerodynamic sources from airflow around the rotor blades. The ever-increasing size of wind turbines has led to increasing issues with the noise levels being emitted.

Tonal noise (or tonal audibility) is directed to noise at a specific frequency. In wind turbines this may be correlated with the generator or rotor speed, and may correlate with resonances of the wind turbine drivetrain. That is, noise may be emitted when a wind turbine operates at a particular generator or rotor speed corresponding to a resonance frequency of one or more structural components of the wind turbine.

A known method for reducing such tonal noise is to introduce so-called `avoidance bands' of operation of the wind turbine, i.e. controlling the wind turbine so that it will not operate in certain rotor speed ranges corresponding to rotor speeds correlated with high levels of tonal noise. However, a disadvantage of such an approach is a loss in efficiency of operation of the wind turbine, e.g. a reduction of produced power, when optimal operation of the turbine would involve a rotor speed in the avoidance band.

Other known approaches for addressing the issue of tonal noise include the installation of tuned mass dampers, or replacing gearboxes with low-vibrating units. However, such approaches are disadvantageous in that provision of the relevant equipment has associated costs, as well as costs associated with downtime of a wind turbine to install/replace such parts. Prior art examples are disclosed in <CIT> and <CIT>.

The inventor of the present invention has realised that noise emissions - in particular, tonal noise emissions - from a wind turbine are not only correlated to wind turbine rotor/generator speed, but also to the variation of wind turbine rotor/generator speed over time. In particular, the inventor has realised that modifying or perturbing the rotor/generator speed to increase its variation over time can result in reduced noise emissions associated with the wind turbine.

According to an aspect of the present invention there is provided a method of reducing noise emissions of a wind turbine. The method comprises receiving data indicative of wind conditions in the vicinity of the wind turbine. The method comprises determining an operational set point signal in accordance with a desired operation of the wind turbine, the operational set point signal being determined in dependence on the received data. The method comprises applying a perturbation signal to the operational set point signal to obtain a modified operational set point signal. The method comprises controlling operation of the wind turbine using the modified operational set point signal to reduce noise emissions of the wind turbine. The perturbation signal is applied such that the modified operational set point signal has greater temporal variation than the operational set point signal.

The method may be particularly directed at reducing tonal audibility emissions from the wind turbine. Wind turbine tonal audibility may be regarded as a difference between the tonality and the audibility criterion in each wind speed bin, where tonality is a difference between the tone level and the level of the masking noise in a critical band around the tone in each wind speed bin, and the audibility criterion is a frequency-dependent criterion curve determined from listening tests and reflecting the subjective response of a 'typical' listener to tones of different frequencies. The concepts of tonality and audibility are dealt with in IEC <NUM>-<NUM> Ed. <NUM> standard.

The method may comprise determining whether application of the perturbation signal is needed in dependence on data indicative of noise emissions of the wind turbine. The method may comprise activating application of the perturbation signal only if it is determined that application of the perturbation signal is needed. Optionally, the data indicative of noise emissions may include the received data indicative of wind conditions.

In some embodiments, determining whether application of the perturbation signal is needed may comprise determining whether an operational parameter of the wind turbine is within a predefined critical range of values. In such embodiments, application of the perturbation signal may be activated only if the operational parameter is determined to be within the prescribed critical range.

In some embodiments, determining whether application of the perturbation signal is needed may comprise determining whether temporal variation of an operational parameter of the wind turbine is below a prescribed threshold variation. In such embodiments, application of the perturbation signal may be activated only if the temporal variation is below the prescribed threshold variation.

Determining temporal variation may comprise determining standard deviation of the operational parameter. The prescribed threshold variation may be a prescribed threshold standard deviation.

The operational parameter may include the operational set point signal.

The operational parameter may include at least one of: wind turbine generator speed; wind turbine power; wind turbine torque; wind turbine tonal audibility; wind speed in the vicinity of the wind turbine; and, wind direction in the vicinity of the wind turbine.

In some embodiments, if it is determined that application of the perturbation signal is not needed, then the method may comprise controlling operation of the wind turbine using the determined operational set point signal.

In some embodiments, if it is determined that the perturbation signal is not needed when application of the perturbation signal is activated, the method may comprise continuing to apply the perturbation signal until a deactivation condition is satisfied. Alternatively, or in addition, if it is determined that the perturbation signal is needed when application of the perturbation signal is deactivated, the method may comprise applying the perturbation signal only if an activation condition is satisfied.

The perturbation signal may be applied such that a temporal mean of the modified operational set point signal is substantially equal to a mean of the operational set point signal.

The perturbation signal may be deterministic. Optionally, the perturbation signal may comprise one, or a combination of, a sine wave signal, a cosine wave signal, a triangular wave signal, and a square wave signal. Optionally, the perturbation signal may be determined based on the received data indicative of wind conditions. Alternatively, the perturbation signal may be a non-deterministic random signal, optionally with a specific temporal variation.

The operational set point signal may be at least one of: a wind turbine generator speed set point signal; and, a wind turbine power set point signal.

In some embodiments, controlling operation of the wind turbine may comprise determining a control output in dependence on the modified operational set point signal. In such embodiments, controlling operation of the wind turbine may comprise using the determined control output to control operation of the wind turbine. Optionally, the control output may include a pitch reference value for controlling pitch of one or more blades of the wind turbine. Optionally, the control output may include a power reference value for controlling power generation of the wind turbine.

According to another aspect of the present invention there is provided a non-transitory, computer-readable storage medium storing instructions thereon that when executed by a processor causes the processor to perform the method described above.

According to another aspect of the present invention there is provided a controller for reducing noise emissions of a wind turbine. The controller is configured to receive data indicative of wind conditions in the vicinity of the wind turbine. The controller is configured to determine an operational set point signal in accordance with a desired operation of the wind turbine, the operational set point signal being determined in dependence on the received data. The controller is configured to apply a perturbation signal to the operational set point signal to obtain a modified operational set point signal, and to control operation of the wind turbine using the modified operational set point signal to reduce noise emissions of the wind turbine. The perturbation signal is applied such that the modified operational set point signal has greater temporal variation than the operational set point signal.

According to another aspect of the present invention there is provided a wind turbine comprising a controller as described above.

Examples of the invention will now be described with reference to the accompanying figures, in which:.

<FIG> shows a wind turbine <NUM> in which an example of the invention may be incorporated. The wind turbine <NUM> comprises a tower <NUM> supporting a nacelle <NUM> to which a rotor <NUM> is mounted. The rotor <NUM> comprises a plurality of wind turbine blades <NUM> that extend radially from a hub <NUM>. In this example, the rotor <NUM> comprises three blades <NUM> and a single rotor <NUM>, although other configurations including any suitable number of blades and rotors are possible.

The wind turbine <NUM> may include one or more different sensors for measuring various features of the operation of the turbine <NUM>, and of the conditions, e.g. wind conditions, in the vicinity of the turbine <NUM>. Shown within each blade <NUM> is an optional blade load sensor <NUM> (in other examples there may be multiple blade load sensors allowing blade loads to be represented by more than a single variable). The sensing element may be a fibre optic strain gauge, a resistive strain gauge, or any other appropriate detector. An optional rotor wind speed and/or direction detector <NUM> is also shown - again, this measurement may be performed in several ways as the skilled person will appreciate, one being through a wind vane and an anemometer, and another through LIDAR, as the skilled person will appreciate from the literature of wind turbine design and control. An optional rotational speed sensor <NUM> is also shown - this may be, for example, in the form of a rotary encoder on a generator shaft of the turbine <NUM>; however, the rotor speed or generator speed may be determined in any suitable manner. Further sensors may additionally or alternatively be included. For instance, an accelerometer for measuring lateral, or side-to-side, oscillations or vibrations of the tower <NUM> may be included at a suitable location, or sensors for measuring indications of the acceleration values of the wind turbine generator or gearbox. A microphone or other acoustic sensor may be included in the turbine <NUM>, or in the vicinity of the turbine <NUM>, to detects levels of noise emissions generated by the wind turbine <NUM>.

<FIG> shows a wind turbine control system <NUM> in accordance with an example of the invention which may be implemented in the wind turbine <NUM> of <FIG>. Here, the control system <NUM> includes an actuator system <NUM> that is controlled by a control unit or (overall) controller <NUM>. In this particular example, the actuator system <NUM> may be, or may comprise, a pitch system for controlling pitch of one or more of the wind turbine blades <NUM> which may include a hydraulic actuator <NUM> arranged to adjust blade pitch in a known manner. The actual position of the actuator <NUM> is controllable by an actuator position control unit <NUM> which provides a positioning command signal to the hydraulic actuator <NUM>. The controller <NUM> and actuator system <NUM> may be replicated for each of the blades <NUM> of the wind turbine <NUM> so that the position of each blade <NUM> may be controlled independently.

The pitch system of the wind turbine <NUM> is just one example of a wind turbine system that may be controlled. The controller <NUM> may also be used to control other wind turbine systems and/or components. For instance, the actuator system <NUM> may be a converter control system where the actuator system <NUM> may be a power converter of the generation system of the wind turbine <NUM> that converts AC power delivered by the generator to a variable-frequency AC power output via a DC link in a process known as `full power conversion', i.e. changing the synchronous speed of the generator independently from the voltage and frequency of the grid.

In one example method of the invention, the pitch of the blades <NUM> of the wind turbine <NUM> may be controlled (individually and/or collectively) according to a control strategy to not only maximise energy production and minimise loads, but also to reduce noise emissions, based on the monitored operation of the wind turbine <NUM>. In particular, blade pitch may be controlled to reduce the tonal noise or tonal audibility caused by a build-up of resonance of one or more structural components of the wind turbine <NUM> - e.g. main shaft, tower, etc. - at specific, critical rotor or generator speeds of the wind turbine <NUM>. That is, the pitch is controlled to ensure that prolonged operation of the wind turbine <NUM> at such a critical speed is avoided. However, unlike previous approaches in which operation of a wind turbine at such a critical rotor speed is prevented, in the method of the invention operation of the wind turbine <NUM> is controlled to perturb the rotor speed away from, or about, a certain value, e.g. a critical rotor speed. Expressed differently, increased temporal variation of the rotor speed is provided to ensure that prolonged or extended operation at a certain rotor speed, e.g. a critical rotor speed, is avoided. In general, therefore, examples of the invention reside in methods that prevent resonances from building up over time, e.g. breaking the resonances by perturbing the system, or disturbing the stability of the system in some way.

A specific example implementing this approach in the controller or control system <NUM> is shown schematically in <FIG>. The controller <NUM> is configured to receive data indicative of wind conditions in the vicinity of the wind turbine <NUM>, e.g. from a wind measurement module or unit <NUM> as indicated in <FIG>. Such data may be obtained from any suitable source. For instance, the data may be indicative of a direct measurement of wind conditions, such as wind speed and/or wind direction, e.g. from the rotor wind speed and/or direction detector <NUM> shown in <FIG>.

Several functional elements or modules of the controller <NUM> are shown. A generator (or rotor) speed optimal set point unit <NUM> receives the wind measurement data from the wind measurement unit <NUM>. The optimal set point unit <NUM> determines an optimal or desired operational set point signal for the generator speed based on the current wind conditions in order to optimise performance of the wind turbine <NUM> according to a particular control strategy, e.g. maximise energy production and/or minimise loads. The optimal set point unit <NUM> then outputs the determined optimal operational set point <NUM> for the generator speed.

A tonality control unit <NUM> determines a perturbation signal that is to be applied to, or superimposed on, the determined optimal set point signal <NUM> in order to reduce tonal noise associated with the wind turbine <NUM>, as will be described in greater detail below. The tonality control unit <NUM> outputs the determined perturbation signal <NUM>, and the perturbation signal <NUM> is applied to, or combined with, the determined optimal set point signal <NUM> at element <NUM>. These signals are combined to obtain a so-called `modified set point signal' for the generator speed when controlling operation of the wind turbine <NUM>.

<FIG> shows the determined modified set point signal <NUM> as being received by a main controller <NUM> of the overall controller or control unit <NUM>. The main controller <NUM> determines outputs that are to be sent to instruct one or more actuation systems of the wind turbine <NUM> so as to cause the wind turbine <NUM> to operate in a desired manner. The pitch reference unit <NUM> and/or a power reference unit <NUM>, receives instructions from the main controller <NUM> for controlling pitch of the blades <NUM> and/or power generation by the wind turbine <NUM>, respectively. The outputs determined by the main controller <NUM> are in particular determined in dependence on the modified operational (generator speed) set point signal <NUM>.

<FIG> shows in greater detail how the perturbation signal <NUM> is applied to the optimal generator speed set point signal <NUM> to obtain the modified or resulting generator speed set point signal. In particular, <FIG> illustrates an example of the optimal set point signal <NUM>. Specifically, the optimal set point signal <NUM> is illustrated as a relatively slowly-varying signal over time. As the optimal set point signal <NUM> is determined in dependence on the wind conditions in the vicinity of the wind turbine <NUM>, a slowly-varying optimal set point signal <NUM> is indicative of slowly-varying wind conditions. For instance, in such a case the wind speed and/or direction may be substantially constant, or varying over a relatively long time period. Such wind conditions may include relatively benign wind conditions, but not include turbulent wind conditions. Specifically, temporal variation of the optimal wind speed signal may be on the same, or a similar, time scale to temporal variation of the wind conditions (e.g. speed, direction, etc.).

<FIG> also illustrates an example of the perturbation signal <NUM>. Specifically, the perturbation signal <NUM> is illustrated as having a temporal variation that is greater than that of the optimal set point signal <NUM>. That is, variation of the perturbation signal <NUM> occurs on a faster time scale that that of the optimal set point signal <NUM>. This means that, when the perturbation signal <NUM> is applied to the optimal set point signal <NUM> at element <NUM>, the resulting set point signal <NUM> is a signal that has greater temporal variation than the optimal set point signal <NUM>.

The perturbation signal <NUM> may be any suitable signal that perturbs the optimal set point about, or away from, a certain (optimal) generator speed set point value or range of values. The perturbation signal <NUM> may be symmetric about a certain generator speed value, e.g. zero generator speed so that a mean value of the modified signal <NUM> is substantially equal to a mean value of the optimal signal <NUM>. The particular form of the perturbation signal may be random or may be deterministic. In the example illustrated in <FIG>, the perturbation signal is in the form of a sine wave signal; however, the signal may take any suitable form, e.g. a cosine wave signal, a triangular wave signal, and a square wave signal, either alternatively or in any suitable combination. The amplitude, period and/or particular form of the perturbation signal <NUM> may be determined based on the detected wind conditions or on the determined optimal set point <NUM>. For instance, there may be certain wind speeds or certain optimal generator speed set points - e.g. those which correspond to increased levels of wind turbine tonal noise - where a perturbation signal having a greater amplitude or greater temporal variation may be desired. In general, it may be desired to perturb the optimal set point by the minimum possible amount that still achieves the desired effect of reduced tonal noise so as to minimise the disturbance on overall operation of the wind turbine.

In the example illustrated in <FIG>, the modified set point signal <NUM> has a greater temporal variation and a greater amplitude than the optimal set point signal (shown as a dashed line), but the mean value of the modified set point signal <NUM> (over time) is substantially equal to that of the optimal set point signal <NUM>. One way in which to increase the temporal variation of the optimal set point signal <NUM> is to increase its standard deviation: in the described example, the modified set point signal <NUM> has a greater standard deviation than the optimal set point signal <NUM>.

The perturbation signal <NUM> may be determined and applied to the optimal set point signal <NUM> in all wind conditions and for all optimal generator speed set point values. However, application of the perturbation signal <NUM> may be of particular benefit in certain wind conditions and/or for certain values of the optimal generator speed set point <NUM>. Specifically, application of the set point signal may be of particular use when the wind conditions mean that the determined optimal generator speed set point is a value, or range of values, of the generator speed that corresponds to operation of the wind turbine <NUM> that results in increased levels of tonal noise. As mentioned above, wind turbine tonal noise may result from prolonged or extended operation of the wind turbine <NUM> at a critical generator speed that corresponds to resonance frequency operation of one or more structural components of the wind turbine <NUM>, such that excitation levels at the resonance frequency are allowed to build. In this respect, relatively stable wind conditions - which correspond to a relatively stable, or slowly-varying, optimal set point - may be the conditions in which application of the perturbation signal <NUM> is needed or desired.

The controller <NUM> may therefore optionally be configured to determine whether perturbation of the optimal set point <NUM> is needed prior to determining or applying the perturbation signal <NUM>. In particular, the controller <NUM> may determine that utilisation of the perturbation signal <NUM> is needed only when optimal operation of the wind turbine <NUM> would result in increased levels of tonal noise. The determination as to whether the perturbation signal is needed may therefore be based on data indicative of noise emissions of the wind turbine <NUM>. Such data may be obtained from one or more different suitable sources. For instance, the data indicative of wind conditions from the wind measurement unit <NUM> may be used as the noise emission data. In particular, it may be known that certain wind speeds correspond to (optimal) operation of the wind turbine <NUM> that results in increased tonal audibility of the wind turbine <NUM>, and therefore it may be determined application of the perturbation signal is needed for such wind speeds. As mentioned, tonal noise may build when there is extended operation of the wind turbine <NUM> at certain critical generator speeds, and so the variance - as well as the absolute value - of the wind speed may be used in determining whether to apply the perturbation signal, e.g. stable or slowly-varying wind speed may mean that application of the perturbation is needed to guard against a build-up of resonance frequency excitation of structural components over time. In this way, the controller <NUM> may activate determination and/or application of the perturbation signal <NUM> only if it is determined that application of the perturbation signal <NUM> is needed.

The data indicative of noise emissions of the wind turbine <NUM> - on which determination of perturbation signal activation is based - may include a direct measurement of the noise being emitted by the wind turbine <NUM>. For instance, such a direct measurement may be received from a microphone or other acoustic sensor in the turbine <NUM>, or in the vicinity of the turbine <NUM>. The controller <NUM> may then determine that activation of the perturbation signal <NUM> is needed when the detected emitted noise from the wind turbine <NUM> exceeds a threshold noise level. The data indicative of noise emissions of the wind turbine <NUM> could also be based on measurements associated with wind turbine operation, such as generator/rotor speed, power generation levels, or torque. It may be that certain levels or values of these parameters are known to correlate with, or result in, high levels of tonal noise, and so activation of the perturbation signal <NUM> could be based on one of more of these parameters being at certain levels, perhaps for a certain amount of time.

More generally, therefore, determining whether application of the perturbation signal <NUM> is needed may include determining whether an operational parameter of the wind turbine <NUM> is within a predefined critical range of values that may result in high levels of tonal noise. Additionally, or alternatively, the determination may include determining whether the temporal variation, e.g. the standard deviation, of the operational parameter is less a threshold variation level. The perturbation signal <NUM> may then be activated only if the operational parameter is determined to be within the prescribed critical range and/or below the threshold variation level. The operational parameter could be one or more of generator speed, wind turbine power, wind turbine torque, wind turbine tonal noise or audibility, wind speed, and wind direction. Application of the perturbation signal <NUM> may then be activated only if the operational parameter is determined to be within the prescribed critical range. Alternatively, or in addition, determining whether application of the perturbation signal <NUM> is needed may include determining whether temporal variation of one of the wind turbine operational parameters is below a prescribed threshold variation, where application of the perturbation signal <NUM> may be activated only if the temporal variation is below the prescribed threshold variation. When the perturbation signal <NUM> is de-activated, or it is determined that it is not needed, operation of the wind turbine <NUM> may be controlled using the optimal set point signal <NUM>, i.e. the main controller <NUM> receives the optimal set point signal <NUM> for use in determining a control output for controlling blade pitch.

In one example, a standard deviation of the generator speed reference is measured and tracked as a moving average, i.e. the average standard deviation is monitored over a certain time period, e.g. <NUM>-second averages. In this way, the moving average value is maintained to track to development of the generator speed. It may be that if the (mean) standard deviation is below a set threshold and the average generator speed reference is within a prescribed threshold speed range, then control to reduce tonal noise emissions is activated, e.g. the perturbation signal <NUM> is activated.

In examples in which application of the perturbation signal is activated or de-activated based on whether predetermined conditions are met, e.g. whether tonal noise levels are above a certain level, further considerations may be made to guard against frequent activation or de-activation of such tonality control measures. For instance, a hysteresis loop may be utilised that sets different conditions for activation and de-activation to avoid frequent switching between the two when operation of the wind turbine <NUM> is in the vicinity of a threshold defining operation with and without the perturbation signal. Another option would be to keep applying the perturbation signal <NUM> for at least a predetermined amount of time after it is activated even if it is determined during the predetermined amount of time that the perturbation signal <NUM> is no longer needed. The perturbation signal <NUM> could also continue to be applied for a predetermined amount of time after it is determined that it is no longer needed. A similar approach could additionally or alternatively be applied after de-activating the perturbation signal <NUM>. More generally, it may be that the perturbation signal <NUM> will continue to be applied until a de-activation condition is satisfied, where such a condition may not just be based on the noise levels being generated, but also on factors to ensure that repeated switching between activation and de-activation is avoided. A similar activation condition may be used when the perturbation signal <NUM> is de-activated.

<FIG> summarises the steps of a method <NUM> in accordance with an embodiment of the invention. At step <NUM>, data indicative of wind conditions in the vicinity of the wind turbine <NUM> is received. This could be data received via a direct wind measurement or could be determined based on some other measurement. For instance, blade load measurements using the blade load sensors <NUM> could be used for this purpose.

At step <NUM>, an operational set point signal <NUM> is determined in accordance with a desired or optimal operation of the wind turbine <NUM>, e.g. according to a desired control strategy to maximise efficiency and/or minimise component loading. The operational set point signal <NUM> - which could be a generator speed set point, for instance - is determined in dependence on the received wind conditions data.

At step <NUM>, a perturbation signal <NUM> is applied to the operational set point signal <NUM> to obtain a modified operational set point signal <NUM>. The perturbation signal <NUM> is applied such that the modified operational set point signal <NUM> has greater temporal variation - e.g. greater standard deviation over a certain time period - than the operational set point signal <NUM>. Optionally, a determination as to whether the perturbation is needed is performed before application of it is performed. Such a determination may be based on the actual or expected levels of tonal noise from the wind turbine, and application of the perturbation signal <NUM> may be activated only if the wind turbine tonal noise levels are above a certain level.

At step <NUM>, operation of the wind turbine <NUM> may be controlled using the modified operational set point signal <NUM> to reduce noise emissions of the wind turbine <NUM>. In a case where the perturbation signal is only activated in certain conditions, then operation of the wind turbine <NUM> may be controlled using the optimal operational set point signal <NUM> when the perturbation signal is de-activated, i.e. when the perturbation signal <NUM> is determined not to be needed.

Many modifications may be made to the described examples without departing from the scope of the appended claims.

In the above-described example, optimal and modified operational set point signals are determined for the generator or rotor speed of the wind turbine. However, in different examples, operational set point signals for different wind turbine operational parameters may alternatively or additionally be determined and used to control operation of the wind turbine. For instance, an optimal and modified wind turbine power set point signal may be determined and used.

In the above-described example, the optimal operational set point signal is determined (based on the detected wind conditions) and then a perturbation signal is applied to obtain the modified operational set point signal. However, in different examples it may be that separate determination of the optimal set point signal and perturbation signal is not performed, and instead the modified set point signal is determined directly (taking into account the contributions from the optimal and perturbation signals).

Examples of the invention could include implementing a perturbation to the generator speed reference so that it does not operate on top of a resonance while also utilising a lookup table (with speed and power constraints) to avoid high levels of excitation that are driven by torque loads caused by powertrain excitations.

Examples of the invention could be used as part of a model predictive control routine for controlling operation of the wind turbine. In particular, the wind turbine operation could be perturbated using a cost function to avoid regions of operation with resonance build-up. Specifically, the cost function could be such that temporal variation, e.g. standard deviation, of the generator speed reference is maintained above a threshold level, at least in certain operating conditions. In essence, the model predictive controller could be configured to such that if wind conditions are stable then the controller acts to increase temporal variation of the wind turbine operation.

Claim 1:
A method (<NUM>) of reducing tonal
noise emissions of a wind turbine (<NUM>), the method (<NUM>)
comprising:
receiving (<NUM>) data indicative of wind conditions in the vicinity of the wind turbine (<NUM>);
determining (<NUM>) an operational set point signal (<NUM>) in accordance with a desired operation of the wind turbine (<NUM>), the operational set point signal (<NUM>) being determined in dependence on the received data;
applying (<NUM>) a perturbation signal (<NUM>) to the operational set point signal (<NUM>) to obtain a modified operational set point signal (<NUM>); and,
controlling (<NUM>) operation of the wind turbine (<NUM>) using the modified operational set point signal (<NUM>) to reduce noise emissions of the wind turbine (<NUM>),
wherein the perturbation signal (<NUM>) is applied such that the modified operational set point signal (<NUM>) has greater temporal variation than the operational set point signal (<NUM>).