METHOD AND SYSTEM FOR
IMPROVING ENERGY CAPTURE EFFICIENCY
FROM AN ENERGY CAPTURE DEVICE
FIELD OF THE INVENTION
The present invention relates to improving the efficiency of energy capture from
an energy capture device. More particularly, but not exclusively, the present invention
relates to the correction of yaw misalignment of an energy capture device, such as a
wind turbine, tidal turbine or the like.
BACKGROUND TO THE INVENTION
In recent years there has been increasing demand for reliable, efficient and cost
effective generation of electricity using renewable energy technologies, including
offshore and onshore wind.
It is recognised that the efficiency of energy capture from a wind turbine
depends on a number of factors, one of which is the relative angle of the wind turbine
to the direction of the wind, and that maximum efficiency may not be achieved where
the wind turbine rotor is not optimally aligned to the incident resource in respect of yaw
angle.
While the yaw angle of modern wind turbines may be adjusted, yaw
misalignment is nevertheless a common problem which prevents operation at
maximum achievable energy capture.
Correction of wind turbine yaw misalignment requires the ability to measure the
wind direction accurately in order for the yaw angle of the wind turbine to be adjusted
as required. Conventional techniques rely on wind direction measurements at or in the
vicinity of the wind turbine's nacelle. However, conventional measurement techniques
are subject to significant inaccuracies. These inaccuracies may, for example, be due
to incorrect set-up during the construction and commissioning of the turbine.
Conventional techniques also suffer from inaccuracies due to the fact that the
measurements are subject to significant flow distortion effects. These inaccuracies
can be large, particularly in the case of complex flow behaviour, for example turbulent
perturbations.
These inaccuracies can have a significant detrimental effect on the efficiency
and consequently the utility of a given wind turbine.
SUMMARY OF THE INVENTION
Aspects of the present invention relate to a method and system for improving
the efficiency of energy capture from an energy capture device by analysis of the
downstream fluid wake created by the energy capture device.
More particularly, but not exclusively, aspects of the present invention relate to
a method and system for use in the correction of yaw misalignment of an energy
capture device, for example but not exclusively a wind energy capture device such as a
wind turbine or a tidal energy capture device such as tidal turbine, by analysing the
downstream fluid wake created by the energy capture device.
According to a first aspect of the present invention there is provided a method
comprising:
acquiring fluid flow data from a downstream fluid wake produced by an energy
capture device; and
providing an output value from the acquired data which is indicative of the yaw
angle of the energy capture device relative to the direction of fluid flow impinging on the
energy capture device.
Operating wind turbines extract energy from the air flow, and as a result create
a downstream "wake" within which the airflow has reduced velocity and increased
turbulence. Accurate measurement of this wake has, historically, been difficult to
achieve given the limitations of anemometers and wind vanes which, individually, only
measure wind speed and direction at a single point. Embodiments of the present
invention beneficially overcome or at least mitigate the drawbacks associated with
conventional techniques for improving efficiency of energy capture and/or correcting
yaw misalignment by measuring the characteristics of the wake behind the energy
capture device. For example, in embodiments where the energy capture device
comprises a wind energy capture device such as a wind turbine, it is possible to
establish whether or not the turbine rotor is fully aligned, that is perpendicular, to the air
flow.
A sensing arrangement may be located on the energy capture device.
Alternatively, or additionally, part or all of the sensing arrangement may be disposed at
a remote location. The sensing arrangement may be positioned at any other suitable
location capable of sensing the wake. The sensing arrangement may be disposed on
the ground. The sensing arrangement may be disposed on a platform, such as an
offshore platform or the like. The sensing arrangement may be disposed on another
energy capture device.
The method may comprise scanning the downstream wake from the energy
capture device using the sensing arrangement.
The method may comprise measuring and/or mapping the shape of the wake.
The method may comprise measuring and/or mapping the intensity of the wake.
The fluid flow data may comprise fluid velocity data. For example, in particular
embodiments the energy capture device may comprise a wind energy capture device
and the fluid flow data may comprise air velocity data. In other embodiments, the
energy capture device may comprise a tidal energy capture device and the fluid flow
data may comprise water velocity data.
The fluid flow data may comprise fluid positional and/or directional data relative
to an axis of the energy capture device. The fluid flow data may comprise data relating
to the azimuth of the fluid relative to the axis of the energy capture device.
The method may comprise acquiring fluid flow velocity data and fluid positional
data from the wake.
The method may comprise determining a core of the wake from the acquired
fluid flow data, the positioning and/or behaviour of the core of the wake corresponding
to the direction of fluid flow impinging on the energy capture device.
The method may comprise plotting the fluid flow data to determine a core of the
wake, the core of the wake corresponding to the direction of fluid flow impinging on the
energy capture device.
The method may comprise plotting the fluid flow velocity data against the fluid
positional data relative to the axis of the energy capture device to determine the core of
the wake.
In particular embodiments, the method may comprise plotting the fluid flow data
from a cross section of the wake to determine the core of the wake.
The core of the wake may comprise the position relative to the axis of the
energy capture device having lowest average flow velocity. For example, when plotting
a curve of the position of the core of the wake on a graph of flow velocity relative to
position relative to the axis of the energy capture device, the core of the wake may
define a minimum value for the acquired data.
Beneficially, the ability to identify the core of the wake, in particular the position
of the core of the wake relative to the axis of the energy capture device, permits an
accurate indication of the true direction of fluid flow impinging on the energy capture
device. For example, in embodiments where the energy capture device comprises a
wind energy capture device such as a wind turbine, identifying the position or azimuth
of the core of the wake relative to the axis of the turbine permits optimal alignment of
the rotor to the incident resource in respect of yaw angle.
Acquiring the fluid flow data may be achieved by any suitable means.
The fluid flow data may be acquired remotely.
The fluid flow data may be acquired by a remote sensing arrangement.
The fluid flow data may be acquired across a three-dimensional flow field.
Beneficially, the ability of acquire the data across a three-dimensional flow field
permits the complex air flows produced by the energy capture device to be mapped
with a high degree of precision and across a wide area.
In particular embodiments, the sensing arrangement may comprise a Lidar
sensing arrangement.
Beneficially, a Lidar sensing arrangement, which uses a light source or laser to
measure air flow velocity across a three-dimensional flow field, permits measurement
of complex air flows across wide areas. Accordingly, by using a Lidar sensing
arrangement to measure the shape and intensity of the wake it is possible to establish
whether or not the turbine is optimally aligned (for example but not exclusively
perpendicular) to the incident resource as it passes through the rotor disc.
Alternatively, the sensing arrangement may comprise a Sodar sensing
arrangement. A Sodar sensing arrangement, which uses a sound source to measure
flow velocity across a three-dimensional flow field, permits measurement of complex
water flows across wide areas. By using a Sodar sensing arrangement to measure the
shape and intensity of the wake it is possible to establish whether or not the turbine is
optimally aligned (for example but not exclusively perpendicular) to the incident
resource as it passes through the rotor disc.
The method may comprise adjusting the yaw angle of the energy capture
device.
In particular, the method may comprise adjusting the yaw angle of the energy
capture device so that the core of the wake corresponds to the axis of the energy
capture device.
By reducing or eliminating the yaw angle between the energy capture device
and the incident resource impinging on the energy capture device, yaw misalignment
may be reduced or eliminated and the efficiency of energy extraction and electricity
generation may be maximised or at least improved.
The output value may be communicated to the control system. For example,
the output value may be communicated directly to the control system so that the control
system adjusts the position of the energy capture device in real time, at a
predetermined time threshold, or when the yaw angle of the energy capture device
relative to the direction of the fluid impinging on the energy capture device exceeds a
particular threshold.
Alternatively, or additionally, the method may comprise communicating the
output value to a remote location, such as to an operator, control centre or the like.
According to a second aspect of the present invention, there is provided a
system comprising:
a sensing arrangement configured to acquire fluid flow data from a downstream
wake of an energy capture device; and
a communication arrangement for providing an output value indicative of the
difference between the average direction of an incident resource and the angle of the
energy capture device.
The sensing arrangement may be mounted or otherwise positioned on the
energy capture device.
The energy capture device may comprise a rotor. The energy capture device
may comprise a plurality of blades.
The energy capture device may comprise a nacelle.
The sensing arrangement may be disposed on a nacelle of the energy capture
device.
The sensing arrangement may be configured to scan the wake from the energy
capture device.
The reference point is at or near to the turbine axis/nacelle axis.
The energy capture device may be of any suitable form and construction.
In particular embodiments, the energy capture device may comprise a wind
energy extraction device, such as a wind turbine or the like.
The sensing arrangement may be of any suitable form and construction.
The sensing arrangement may comprise a remote sensing arrangement.
The sensing arrangement may be configured to measure fluid flow velocity,
such as airflow velocity, across a three-dimensional flow field.
In particular embodiment, the sensing arrangement may comprise a Lidar
sensing arrangement.
Alternatively, the sensing arrangement may comprise a Sodar sensing
arrangement.
The system may comprise a control system.
The control system may be configured to adjust the position, for example the
yaw angle, of the energy capture device.
The communication arrangement may be of any suitable form and construction.
The communication arrangement may be configured to transmit the output
value to the control system.
Alternatively, or additionally, the communication arrangement may be
configured to transmit the output value to a remote location.
It should be understood that the features defined above in accordance with any
aspect of the present invention or below in relation to any specific embodiment of the
invention may be utilised, either alone or in combination with any other defined feature,
in any other aspect or embodiment of the invention.
BRIEF DESCRIPTION OF THE DRAWINGS
These and other aspects of the present invention will now be described, by way
of example only, with reference to the accompanying drawings, in which:
Figure 1 is a diagrammatic view of a wind turbine system according to an
embodiment of the present invention;
Figure 2 shows a sensing arrangement for use in the present invention;
Figure 3 is a diagrammatic plan view of the wind turbine system shown in
Figure 1, in a first position;
Figure 4 is a graph showing a plot of wind speed against azimuth for the wind
turbine system in the first position shown in Figure 3 ;
Figure 5 is a diagrammatic plan view of the wind turbine system shown in
Figure 1, in a second position;
Figure 6 is a graph showing a plot of wind speed against azimuth for the wind
turbine system in the second position shown in Figure 5 .
Figure 7 is a diagrammatic view of a tidal turbine system according to another
embodiment of the present invention;
Figure 8 shows a sensing arrangement for use in the present invention;
Figure 9 is a diagrammatic plan view of the tidal turbine system shown in Figure
7 , in a first position;
Figure 10 is a graph showing a plot of water speed against azimuth for the tidal
turbine system in the first position shown in Figure 9 ;
Figure 11 is a diagrammatic plan view of the tidal turbine system shown in
Figure 7 , in a second position;
Figure 12 is a graph showing a plot of water speed against azimuth for the tidal
turbine system in the second position shown in Figure 11; and
Figure 13 is a diagrammatic view of a turbine system according to another
embodiment of the present invention.
DETAILED DESCRIPTION OF THE DRAWINGS
Referring first to Figure 1, there is shown a diagrammatic perspective view of a
system 10 according to an embodiment of the present invention.
In the illustrated embodiment, the system 10 comprises a wind turbine system.
However, it will be recognised that the system 10 may take other forms and may for
example comprise a tidal energy capture turbine system or the like.
As shown in Figure 1, the wind turbine system 10 comprises a wind turbine 12
having a tower 14, a nacelle 16 and a hub 18 having a plurality of radially extending
blades 20. The hub 18 is operatively coupled to an electrical generator 22 via a drive
shaft 24. In the illustrated embodiment, a gear arrangement 26 in the form of a gear
box is provided, although in other embodiments a gear arrangement may not be
provided. In the illustrated embodiment, the turbine 12 further comprises a controller
28, the controller 28 operatively coupled to a yaw drive arrangement 30 capable of
adjusting the angle of the turbine 12.
In use, the kinetic energy of wind W impinging on the blades 20 drives rotation
of the hub 18 relative to the nacelle 16, this kinetic energy being transmitted via the
drive shaft 24 (and the gear arrangement 26 where provided) to the electrical generator
22 where it is converted into electricity.
As shown in Figure 1 and with reference also to Figure 2 , the system 10 further
comprises a sensing arrangement 32 which, in the illustrated embodiment, is disposed
on the nacelle 16 of the wind turbine 12. It will be recognised, however, that the
sensing arrangement 32 may be provided at other suitable locations, such as a remote
location, a platform, on the ground or on one or more other turbine.
In use, and referring also to Figure 3 which shows a diagrammatic plan view of
the wind turbine system 10 in a first position, the sensing arrangement 32 is configured
to acquire air flow data from a downstream wake 34 produced by the rotating blades 20
of the wind turbine 12. In the illustrated embodiment, the sensing arrangement 32
comprises a Lidar unit 35 having an optical source 36 - in the illustrated embodiment a
laser source - for transmitting light beams over the desired flow field, which in
embodiments of the invention comprises the downstream fluid wake 34 produced by
the blades 20. The unit 35 further comprises or is operatively associated with a
receiver 38 - in the illustrated embodiment an optical antenna -for detecting the light
reflected back from the wake 34. In the illustrated embodiment, this is achieved by
measuring the back-scatter of light radiation which is reflected by natural aerosols
carried by the wind, such as dust, water droplets, pollution, pollen, salt crystals or the
like.
In use, the sensing arrangement 32 acquires data relating to the air flow
velocity in the wake 34 across a three-dimensional flow field, which data is then
processed to determine the relative angle of the wind turbine 12 and the average
direction D of the incident resource W.
To illustrate the system and method of the present invention, operation of the
wind turbine system 10 will now be described with reference to Figures 3 to 6 .
As described above, Figure 3 shows a plan view of the wind turbine system 10
in a first position, in which the wind turbine 12 is positioned at an angle Q to the
average direction D of the wind W.
The sensing arrangement 32 is positioned at, or calibrated to, the rotational axis
40 of the turbine 12 and, in use, the sensing arrangement 32 acquires wind speed and
azimuth data relative to the turbine axis 32 by scanning a three-dimensional field which
includes the wake 34 produced by the blades 20 of the turbine 12, in the illustrated
embodiment the scan represented by reference numeral 42.
A graph showing a plot of the acquired wind speed and azimuth data for cross
section A-A of wake 34 when the turbine 12 is in the first position is shown in Figure 4 .
As can be seen from Figures 3 and 4 , the wake 34 produced by the blades 20 of the
turbine 12 is deflected and a core 44 of the wake 34 - as represented in the graph by
the lowest point - is out of alignment with the rotational axis 40 of the turbine 12, the
azimuth a of the core 44 relative to the turbine rotational axis 40 corresponding to the
misalignment of the turbine 12 relative to the average direction of the incident resource
D.
In this way, an output indicative of the misalignment of the turbine 12 relative to
the wind direction D may be produced, which may be communicated to an operator or
communicated directly to the control system where it may be used to alter the angle of
the turbine 12 from the position shown in Figure 3 to the position shown in Figure 5 .
Figure 5 shows a plan view of the wind turbine system 10 in the second
position, in which the wind turbine 12 is positioned in exact alignment with the rotational
axis 40 of the turbine 12 and Figure 6 shows a graph showing a plot of the acquired
wind speed and azimuth data for cross section B-B of wake 34 when the turbine 12 is
in the second position. As can be seen from Figures 5 and 6 , the wake 34 produced by
the blades 20 of the turbine 12 is symmetrical about the turbine rotational axis 40 and
the core 44 of the wake 34 - as represented in the graph by the lowest point - is
aligned with the rotational axis 40 of the turbine 12.
By utilising the method and system of the present invention, it is possible to
establish the correct yaw alignment with a high degree of accuracy and thereby
maximise turbine efficiency and energy production.
It should be understood that the embodiments described herein are merely
exemplary and that various modifications may be made thereto without departing from
the scope of the invention.
For example, whereas the particular embodiment described above relates to a
wind energy capture system using a Lidar sensing arrangement, other embodiments of
the invention may take other forms.
Referring now to Figures 7 to 12, there is shown a system 110 according to an
alternative embodiment of the invention. The system 110 comprises a tidal energy
capture system for location in a body of water S and which utilise a Sodar (Sound
Detection and Ranging) sensing arrangement, although it will be recognised that other
sensing arrangements may be used where appropriate.
As shown in Figure 7 , the tidal turbine system 110 comprises a tidal turbine 112
having a tower 114, a nacelle 116 and a hub 118 having a plurality of radially extending
blades 120. The hub 118 is operatively coupled to an electrical generator 122 via a
drive shaft 124. In the illustrated embodiment, a gear arrangement 126 in the form of a
gear box is provided, although in other embodiments a gear arrangement may not be
provided. In the illustrated embodiment, the turbine 112 further comprises a controller
128, the controller 128 operatively coupled to a yaw drive arrangement 130 capable of
adjusting the angle of the turbine 112 in the body of water.
In use, the kinetic energy of water impinging on the blades 120 drives rotation
of the hub 118 relative to the nacelle 116, this kinetic energy being transmitted via the
drive shaft 124 (and the gear arrangement 126 where provided) to the electrical
generator 122 where it is converted into electricity.
As shown in Figure 7 and with reference also to Figure 8 , the system 110
further comprises a sensing arrangement 132 which, in the illustrated embodiment, is
disposed on the nacelle 116 of the tidal turbine 112. It will be recognised, however,
that the sensing arrangement 132 may be provided at other suitable locations, such as
a remote location, a platform, on the seabed or on one or more other turbine.
In use, and referring also to Figure 9 which shows a diagrammatic plan view of
the tidal turbine system 110 in a first position, the sensing arrangement 132 is
configured to acquire flow data from a downstream wake 134 produced by the rotating
blades 120 of the tidal turbine 112. In the illustrated embodiment, the sensing
arrangement 132 comprises a Sodar unit 135 having a sound source 136 for
transmitting sound pulses over the desired flow field, which in embodiments of the
invention comprises the downstream fluid wake 134 produced by the blades 120. The
unit 135 further comprises or is operatively associated with a receiver 138 for detecting
the sound reflected back from the wake 134.
In the illustrated embodiment, this is achieved by emitting a short pulse of
sound at a certain frequency. The sound propagates outwards and upwards, while at
the same time a part of the sound is reflected back. The Doppler frequency shift of the
received signal is proportional to the fluid speed aligned to the transmission sound
path. By combining three or five of these pulses, for example one along the vertical
and two or four inclined to the vertical, the three-dimensional velocity field of both the
mean values and the turbulent values is calculated.
In use, the sensing arrangement 132 acquires data relating to the flow velocity
in the wake 134 across a three-dimensional flow field, which data is then processed to
determine the relative angle of the wind turbine 112 and the average direction D' of the
incident resource W .
To illustrate the system and method of the present invention, operation of the
wind turbine system 110 will now be described with reference to Figures 9 to 12.
As described above, Figure 9 shows a plan view of the tidal turbine system 110
in a first position, in which the tidal turbine 12 is positioned at an angle ' to the
average direction D' of the incident resource W .
The sensing arrangement 132 is positioned at, or calibrated to, the rotational
axis 140 of the turbine 112 and, in use, the sensing arrangement 132 acquires flow
speed and azimuth data relative to the turbine axis 132 by scanning a threedimensional
field which includes the wake 134 produced by the blades 120 of the
turbine 112, in the illustrated embodiment the scan represented by reference numeral
142.
A graph showing a plot of the acquired flow speed and azimuth data for cross
section C-C of wake 134 when the turbine 112 is in the first position is shown in Figure
10. As can be seen from Figures 9 and 10, the wake 134 produced by the blades 120
of the turbine 112 is deflected and a core 144 of the wake 134 - as represented in the
graph by the lowest point - is out of alignment with the rotational axis 40 of the turbine
112, the azimuth a' of the core 144 relative to the turbine rotational axis 140
corresponding to the misalignment of the turbine 112 relative to the average direction
of the incident resource D'.
In this way, an output indicative of the misalignment of the turbine 112 relative
to the flow direction D may be produced, which may be communicated to an operator
or communicated directly to the control system where it may be used to alter the angle
of the turbine 112 from the position shown in Figure 9 to the position shown in Figure
11.
Figure 9 shows a plan view of the tidal turbine system 110 in the second
position, in which the tidal turbine 112 is positioned in exact alignment with the
rotational axis 140 of the turbine 112 and Figure 12 shows a graph showing a plot of
the acquired flow speed and azimuth data for cross section D-D of wake 134 when the
turbine 112 is in the second position. As can be seen from Figures 11 and 12, the
wake 134 produced by the blades 120 of the turbine 112 is symmetrical about the
turbine rotational axis 140 and the core 144 of the wake 134 - as represented in the
graph by the lowest point - is aligned with the rotational axis 140 of the turbine 112.
Whereas in the embodiments described above, the sensing arrangement is
disposed on the turbine, it will be recognised that the sensing arrangement may be
positioned at any other suitable location capable of sensing the wake.
Referring now to Figure 13, there is shown a system 210 according to an
alternative embodiment of the invention. The system 210 is similar to the systems 10,
110 described above with the difference that the sensing arrangement 232 is located
on the ground.
As shown in Figure 13, the turbine system 210 comprises a turbine 212 having
a tower 214, a nacelle 216 and a hub 218 having a plurality of radially extending blades
220. The hub 218 is operatively coupled to an electrical generator 222 via a drive shaft
224. In the illustrated embodiment, a gear arrangement 226 in the form of a gear box
is provided, although in other embodiments a gear arrangement may not be provided.
In the illustrated embodiment, the turbine 212 further comprises a controller 228, the
controller 228 operatively coupled to a yaw drive arrangement 230 capable of adjusting
the angle of the turbine 212.
In use, the kinetic energy of incident resource (for example air or water) on the
blades 220 drives rotation of the hub 218 relative to the nacelle 216, this kinetic energy
being transmitted via the drive shaft 224 (and the gear arrangement 226 where
provided) to the electrical generator 222 where it is converted into electricity.
As described above, in this embodiment the sensing arrangement 232 is
disposed on the ground and is configured to acquire flow data from a downstream
wake 234 produced by the rotating blades 220 of the turbine 212. The sensing
arrangement 232 itself may be of any suitable form and may, for example comprise a
Lidar sensing arrangement such as the sensing arrangement 32 described above or a
Sodar sensing arrangement such as the sensing arrangement 132 described above.
It will be recognised that the method and system of the present invention may
be used in number of different ways and at different instances during the working life of
the energy capture device. For example, the technique may involve short-term
application of the sensing arrangement, after which the alignment may be corrected
and the sensing arrangement is removed to be used elsewhere. Alternatively the
sensing arrangement may be left in-situ for continuous application.

CLAIMS
1. A method comprising:
acquiring fluid flow data from a downstream fluid wake produced by an energy
capture device; and
providing an output value from the acquired data which is indicative of the yaw
angle of the energy capture device relative to the direction of fluid flow impinging on the
energy capture device.
2 . The method of claim 1, comprising scanning the downstream wake from the
energy capture device using a sensing arrangement.
3 . The method of claim 1 or 2 , comprising measuring and/or mapping the shape of
the wake.
4 . The method of claim 1, 2 or 3 , comprising measuring and/or mapping the
intensity of the wake.
5 . The method of any preceding claim, wherein the fluid flow data comprises fluid
velocity data.
6 . The method of claim 5 , wherein the fluid flow data comprises air velocity data.
7 . The method of any preceding claim, wherein the fluid flow data comprises fluid
positional and/or directional data relative to an axis of the energy capture device.
8 . The method of any preceding claim, wherein the fluid flow data comprises data
relating to the azimuth of the fluid relative to the axis of the energy capture device.
9 . The method of any preceding claim, comprising acquiring fluid flow velocity data
and fluid positional data from the wake.
10. The method of any preceding claim, comprising determining a core of the wake
from the acquired fluid flow data.
11. The method of any preceding claim, comprising plotting the fluid flow data to
determine a core of the wake.
12. The method of any preceding claim, comprising plotting the fluid flow velocity
data against the fluid positional data relative to the axis of the energy capture device to
determine the core of the wake.
13. The method of claim 11 or 12, comprising plotting the fluid flow data from a
cross section of the wake to determine the core of the wake.
14. The method of any preceding claim, wherein the fluid flow data is acquired
remotely.
15. The method of claim 14, wherein the fluid flow data is acquired by a remote
sensing arrangement.
16. The method of any preceding claim, wherein the fluid flow data is acquired
across a three-dimensional flow field.
17. The method of any preceding claim, wherein the sensing arrangement
comprises a Lidar sensing arrangement.
18. The method of any one of claims 1 to 16, wherein the sensing arrangement
comprises a Sodar sensing arrangement.
19. The method of any preceding claim, comprising adjusting the yaw angle of the
energy capture device.
20. The method of claim 19, comprising adjusting the yaw angle of the energy
capture device so that the core of the wake corresponds to the axis of the energy
capture device.
2 1. The method of any preceding claim, comprising communicating the output
value to the control system.
22. The method of claim 21, comprising communicating the output directly to the
control system.
23. The method of claim 22, comprising communicating the output directly to the
control system so that the control system adjusts the position of the energy capture
device in real time.
24. The method of claim 22 or 23, comprising communicating the output directly to
the control system so that the control system adjusts the position of the energy capture
device at a predetermined time threshold.
25. The method of claim 22, 23 or 24, comprising communicating the output directly
to the control system so that the control system adjusts the position of the energy
capture device when the yaw angle of the energy capture device relative to the
direction of the fluid impinging on the energy capture device exceeds a particular
threshold.
26. The method of any one of claims 1 to 2 1, comprising communicating the output
value to a remote location.
27. A system comprising:
a sensing arrangement configured to acquire fluid flow data from a downstream
wake of an energy capture device; and
a communication arrangement for providing an output value indicative of the
difference between the average direction of an incident resource and the angle of the
energy capture device.
28. The system of claim 27, wherein the sensing arrangement is mounted or
otherwise positioned on the energy capture device.
29. The system of claim 27 or 28, wherein the sensing arrangement is configured to
scan the wake from the energy capture device.
30. The system of claim 27, 28 or 29, wherein the energy capture device comprises
a wind energy extraction device.
3 1. The system of any one of claims 27 to 30, wherein the energy capture device
comprises a tidal energy extraction device.
32. The system of any one of claims 27 to 3 1, wherein the sensing arrangement
comprises a remote sensing arrangement.
33. The system of any one of claims 27 to 32, wherein the sensing arrangement is
configured to measure fluid flow velocity.
34. The system of claim 33, wherein the sensing arrangement is configured to
measure fluid flow velocity across a three-dimensional flow field.
35. The system of any one of claims 27 to 34, wherein the sensing arrangement
comprises a Lidar sensing arrangement.
36. The system of any one of claims 27 to 30 or 32 to 34 when dependent on claim
30, wherein the sensing arrangement comprises a Sodar sensing arrangement.
37. The system of any one of claims 27 to 36, comprising a control system.
38. The system of claim 37, wherein the control system is configured to adjust the
position of the energy capture device.
39. The system of any one of claims 27 to 38, wherein the communication
arrangement is configured to transmit the output value to the control system.
40. The system of any one of claims 27 to 39, wherein the communication
arrangement is configured to transmit the output value to a remote location.