WO2017033009A1 - Dispositif de détection à distance - Google Patents

Dispositif de détection à distance Download PDF

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Publication number
WO2017033009A1
WO2017033009A1 PCT/GB2016/052626 GB2016052626W WO2017033009A1 WO 2017033009 A1 WO2017033009 A1 WO 2017033009A1 GB 2016052626 W GB2016052626 W GB 2016052626W WO 2017033009 A1 WO2017033009 A1 WO 2017033009A1
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WO
WIPO (PCT)
Prior art keywords
remote sensing
sensing device
source
arrangement
signal
Prior art date
Application number
PCT/GB2016/052626
Other languages
English (en)
Inventor
Peter James Macdonald CLIVE
William John BARKER
Original Assignee
Sgurrenergy Limited
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 Sgurrenergy Limited filed Critical Sgurrenergy Limited
Publication of WO2017033009A1 publication Critical patent/WO2017033009A1/fr

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Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01S—RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES
    • G01S17/00—Systems using the reflection or reradiation of electromagnetic waves other than radio waves, e.g. lidar systems
    • G01S17/88—Lidar systems specially adapted for specific applications
    • G01S17/95—Lidar systems specially adapted for specific applications for meteorological use
    • 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
    • F03B—MACHINES OR ENGINES FOR LIQUIDS
    • F03B13/00—Adaptations of machines or engines for special use; Combinations of machines or engines with driving or driven apparatus; Power stations or aggregates
    • F03B13/12—Adaptations of machines or engines for special use; Combinations of machines or engines with driving or driven apparatus; Power stations or aggregates characterised by using wave or tide energy
    • F03B13/26—Adaptations of machines or engines for special use; Combinations of machines or engines with driving or driven apparatus; Power stations or aggregates characterised by using wave or tide energy using tide energy
    • F03B13/264—Adaptations of machines or engines for special use; Combinations of machines or engines with driving or driven apparatus; Power stations or aggregates characterised by using wave or tide energy using tide energy using the horizontal flow of water resulting from tide movement
    • 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
    • F03D17/00—Monitoring or testing of wind motors, e.g. diagnostics
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01P—MEASURING LINEAR OR ANGULAR SPEED, ACCELERATION, DECELERATION, OR SHOCK; INDICATING PRESENCE, ABSENCE, OR DIRECTION, OF MOVEMENT
    • G01P5/00—Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft
    • G01P5/26—Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft by measuring the direct influence of the streaming fluid on the properties of a detecting optical wave
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01S—RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES
    • G01S17/00—Systems using the reflection or reradiation of electromagnetic waves other than radio waves, e.g. lidar systems
    • G01S17/02—Systems using the reflection of electromagnetic waves other than radio waves
    • G01S17/50—Systems of measurement based on relative movement of target
    • G01S17/58—Velocity or trajectory determination systems; Sense-of-movement determination systems
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01S—RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES
    • G01S7/00—Details of systems according to groups G01S13/00, G01S15/00, G01S17/00
    • G01S7/48—Details of systems according to groups G01S13/00, G01S15/00, G01S17/00 of systems according to group G01S17/00
    • G01S7/481—Constructional features, e.g. arrangements of optical elements
    • G01S7/4814—Constructional features, e.g. arrangements of optical elements of transmitters alone
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01S—RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES
    • G01S7/00—Details of systems according to groups G01S13/00, G01S15/00, G01S17/00
    • G01S7/48—Details of systems according to groups G01S13/00, G01S15/00, G01S17/00 of systems according to group G01S17/00
    • G01S7/481—Constructional features, e.g. arrangements of optical elements
    • G01S7/4817—Constructional features, e.g. arrangements of optical elements relating to scanning
    • 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
    • F05B2210/00—Working fluid
    • F05B2210/16—Air or water being indistinctly used as working fluid, i.e. the machine can work equally with air or water without any modification
    • 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
    • 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
    • F05B2270/80—Devices generating input signals, e.g. transducers, sensors, cameras or strain gauges
    • F05B2270/804—Optical devices
    • F05B2270/8042—Lidar systems
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
    • Y02A90/00—Technologies having an indirect contribution to adaptation to climate change
    • Y02A90/10—Information and communication technologies [ICT] supporting adaptation to climate change, e.g. for weather forecasting or climate simulation
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E10/00—Energy generation through renewable energy sources
    • Y02E10/30—Energy from the sea, e.g. using wave energy or salinity gradient

Definitions

  • 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 a remote sensing device for use in a system for the correction of yaw misalignment of an energy capture device, such as a wind turbine, tidal turbine or the like.
  • 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.
  • 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.
  • the remote sensing device suitable for use in a system for improving the efficiency of energy capture from an energy capture device.
  • the remote sensing device may be configured for use in a 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.
  • the remote sensing device may be configured to emit a signal to a remote volume, such as a remote air volume or a remote water volume, and detect a return signal to facilitate properties of the remote volume to be determined.
  • a remote volume such as a remote air volume or a remote water volume
  • Embodiments of the present invention may beneficially apply the principles of interferometry to detect the Doppler (frequency) shift imparted to a directionally orientated signal through interaction with particles moving freely within a flow of air.
  • This frequency shift is directly proportional to the speed of movement of the particles along the line of sight (LoS) of the emitted signal.
  • the reflected (return) signal onto which this frequency shift has been imparted may be gathered and mixed with the original emitted signal and interference between the signals enables the frequency shift, and therefore particle speed along the LoS may be detected.
  • Embodiments of the present invention may alternatively or additionally beneficially apply the principles of spectroscopy to directly detect the Doppler (frequency) shift.
  • the range of frequencies of the reflected (return) signal onto which this frequency shift has been imparted may be analysed using filters to selected and compare the return signal at specific frequency values and the Doppler shift may be inferred from this comparison.
  • the remote sensing device may comprise a laser system.
  • the laser system may comprise a lidar system.
  • the laser system e.g. the lidar system, may be used to detect the directional misalignment of a wind power generator (WPG) through measurement of air velocity differences in the wake of the generator.
  • WPG wind power generator
  • the remote sensing device may comprise a source.
  • the source may comprise a radiation source.
  • the source may comprise a laser.
  • the source may comprise a seed laser.
  • the source e.g. the seed laser
  • the source may be configured to generate a narrow linewidth continuous wave laser signal with high frequency stability.
  • the frequency shift of the return signal is small compared to the frequency of the emitted signal so a narrow line-width and high stability is required to enable the accurate detection of particle speed.
  • the source may comprise a splitter.
  • the splitter may comprise an optical splitter.
  • the source may comprise a modulator.
  • the modulator may comprise an acousto-optic modulator (AOM).
  • AOM acousto-optic modulator
  • the source may comprise an amplifier.
  • the amplifier may comprise an optical amplifier.
  • the amplifier may comprise a pulsed optical amplifier.
  • the source may comprise a circulator.
  • the circulator may comprise an optical circulator.
  • the remote sensing device may be configured to emit a signal to a remote volume, for example a remote fluid volume, such as a remote air volume or a remote water volume.
  • a remote fluid volume such as a remote air volume or a remote water volume.
  • the remote sensing device may comprise an emitter for transmitting the signal to the remote volume.
  • the signal may comprise radiation from the source.
  • the signal may comprise a paramount signal, lidar beam or the like.
  • the emitter may be connected to the source and may take a number of different forms, as will be described further below.
  • the emitter may comprise a telescope, such as an optical telescope.
  • the emitter may comprise a plurality of the telescopes.
  • the emitter may comprise an array of N telescopes.
  • the emitter may comprise a horizontal array of telescopes.
  • the telescopes may be independently connected to the source.
  • the telescopes may be independently connected to the circulator.
  • a coupler may be provided for coupling the telescopes to the source.
  • the coupler may comprise an optical switch.
  • the emitter may comprise a scanning arrangement.
  • the scanning arrangement may be connected to the source.
  • the scanning arrangement may comprise a telescope, such as an optical telescope.
  • the scanning arrangement may comprise a mirror onto which the signal, e.g. Iidar beam, is directed and whose orientation may be adjusted to scan the signal, e.g. Iidar beam through a variety of different azimuth angles.
  • the scanning arrangement may comprise a rotating multi-faceted mirror, such as, for example, an octagonal or hexagonal mirror, onto which the signal, e.g. Iidar beam, is directed such that rotation of the mirror scans the signal through a range of azimuth angles.
  • a rotating multi-faceted mirror such as, for example, an octagonal or hexagonal mirror, onto which the signal, e.g. Iidar beam, is directed such that rotation of the mirror scans the signal through a range of azimuth angles.
  • the scanning arrangement may comprise a rotating prism through which the signal, e.g. Iidar beam, is directed such that rotation of the prism scans the signal, e.g. Iidar beam through a range of azimuth angles.
  • the remote sensing device may comprise or may be operatively associated with a receiver for detecting a return signal, such as radiation returned from the remote volume.
  • the receiver may comprise a detector.
  • the receiver may comprise a converter.
  • the converter may comprise an analogue-to-digital converter.
  • the receiver in particular embodiments the analogue-to-digital converter, may be interfaced to a processing system, such as a digital processing system.
  • the remote sensing device may comprise or may be operatively associated with a processor, such as for analysing the detected return signal.
  • the remote sensing device may comprise connectors for connecting together the source, the emitter and the receiver.
  • a connector (“the first connector”) may connect the source and the emitter.
  • the first connector may connect the circulator and the coupler.
  • the first connector may connect the circulator and the scanning arrangement.
  • the first connector may connect the circulator and the mirror or prism.
  • a connector (“the second connector”) may connect the source and the receiver.
  • the second connector may connect the detector to the splitter.
  • a connector (“the third connector”) may connect the source and the receiver.
  • the third connector may connect the detector and the circulator.
  • One or more of the first, second and third connectors may comprise a signal carrier.
  • One or more of the connectors may comprise a waveguide.
  • one or more of the connectors may comprise at least one optical fibre.
  • the optical fibre or fibres may comprise polarisation maintaining optical fibre.
  • one or more of the connectors may comprise an electrical connector, or other suitable connector.
  • Connectors may be used to connect components of the source together.
  • first source connector may connect the laser and the splitter.
  • second source connector may connect the splitter and the modulator.
  • third source connector may connect the modulator and the amplifier.
  • fourth source connector may connect the amplifier and the circulator.
  • One or more of the connectors of the source may comprise a signal carrier.
  • One or more of the connectors may comprise a waveguide.
  • one or more of the connectors of the source may comprise at least one optical fibre.
  • the optical fibre or fibres may comprise polarisation maintaining optical fibre.
  • one or more of the connectors of the source may comprise an electrical connector, or other suitable connector.
  • Connectors may be used to connect components of the emitter together.
  • a plurality of emitter connectors may be provided, each emitter connector connecting the coupler and one of the telescopes.
  • a connector (“first emitter connector” may connect the coupler and a first of the telescopes
  • another connector (“second emitter connector”) may connect the coupler and a second of the telescopes
  • another connector (“third emitter connector”) may connect the coupler and a third of the telescopes
  • One or more of the connectors of the emitter may comprise a signal carrier.
  • One or more of the connectors may comprise a waveguide.
  • one or more of the connectors of the emitter may comprise at least one optical fibre.
  • the optical fibre or fibres may comprise polarisation maintaining optical fibre.
  • one or more of the connectors of the emitter may comprise an electrical connector, or other suitable connector.
  • Connectors may be used to connect components of the receiver together.
  • first detector connector may connect the converter, e.g. analogue to digital converter, and the detector.
  • second detector connector may connect the converter and the processing system.
  • the remote sensing device may in particular embodiments have a pulsed mode of operation in which the signal e.g. a short burst of radiation is emitted and a return signal is then chronologically recorded.
  • the return signal can be processed according to the elapsed time from pulse emission to determine the range from the remote sensing device from which the signal was returned.
  • the source e.g. the seed laser
  • the source may be configured to generate a narrow linewidth continuous wave laser signal with high frequency stability. The frequency shift of the return signal is small compared to the frequency of the emitted signal so a narrow line-width and high stability is required to enable the accurate detection of particle speed.
  • the output of the amplifier may be fed through the circulator and may be connected to the coupler. It will be recognised that beyond the circulator the emitted and received signals share the same optical path and in embodiments of the present invention, the circulator acts as a splitter to separate the emitted and returned signals by means of their polarisation, feeding the return signal into the detector, for example by means of a polarisation maintaining optical fibre.
  • the source may be connected to the telescopes via the coupler and through separate connectors, such as optical fibres.
  • the coupler can be instructed to make a connection between the circulator and each of the telescopes in isolation.
  • the emitter may comprise a scanning arrangement rather than an arrangement of telescopes connected to a switch.
  • the scanning arrangement may comprise a single telescope connected to a mirror or prism whose orientation can be adjusted to emit and receive the emitted and returned signal along lines of sight with different azimuths.
  • the detector may mix the emitted and returned signals producing an interference signal that is digitised by the analogue-to-digital converter.
  • the digitised signal may then be processed by the digital processing system to extract an estimate of the air speed along the LoS of the emitted beam of radiation.
  • the remote sensing device may in particular embodiments be configured for use in a method or 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 and aspects of the present invention also 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.
  • a wind energy capture device such as a wind turbine or a tidal energy capture device such as tidal turbine
  • Embodiments of the present invention may 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.
  • the energy capture device comprises a wind energy capture device such as a wind turbine
  • 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 sensing arrangement may comprise the remote sensing device according to the first aspect of the invention.
  • 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.
  • the energy capture device may comprise a wind energy capture device and the fluid flow data may comprise air velocity data.
  • 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.
  • 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.
  • the core of the wake may define a minimum value for the acquired data.
  • a different variation in velocity relative to position may be used to detect the core of the wake. For example, in the near-wake immediately behind a central hub of an energy capture device, flow velocity may be higher than in adjacent regions and this may be adopted as the wake signature used to detected the core of the wake.
  • 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.
  • 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.
  • the fluid flow data may be acquired across a two-dimensional flow field.
  • 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.
  • the sensing arrangement may comprise a Lidar sensing arrangement.
  • a Lidar sensing arrangement which uses a light source or laser to measure air flow velocity across a three-dimensional or two-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.
  • the sensing arrangement may comprise a Sodar sensing arrangement, for example, an Acoustic Doppler Current Profiler (ADCP).
  • 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.
  • 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.
  • 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.
  • 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.
  • the method may comprise communicating the output value to a remote location, such as to an operator, control centre or the like.
  • a system comprising:
  • a sensing arrangement configured to acquire fluid flow data from a downstream wake of an energy capture device
  • 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 comprise the remote sensing device according to the first aspect of the invention.
  • 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.
  • 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.
  • the sensing arrangement may comprise a Lidar sensing arrangement.
  • 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.
  • the communication arrangement may be configured to transmit the output value to a remote location.
  • Figure 1 shows a schematic view of a remote sensing device according to a first embodiment of the present invention
  • Figure 2 shows a schematic view of a remote sensing device according to a second embodiment of the present invention
  • Figure 3 shows a plan view of a scanning arrangement of the remote sensing device shown in Figure 2;
  • Figure 4 shows a side view of the scanning arrangement of the remote sensing device shown in Figure 2;
  • Figure 5 is a diagrammatic view of a wind turbine system according to an embodiment of the present invention, and showing an application of the remote sensing devices shown in Figures 1 or 2 in measuring air speed and direction across a wind power generator wake;
  • Figure 6 shows a sensing arrangement for use in the system shown in Figure 5;
  • Figure 7 is a diagrammatic plan view of the wind turbine system shown in Figure 5, in a first position
  • Figure 8 is a graph showing a plot of wind speed against azimuth for the wind turbine system in the first position shown in Figure 7;
  • Figure 9 is a diagrammatic plan view of the wind turbine system shown in Figure 5, in a second position;
  • Figure 10 is a graph showing a plot of wind speed against azimuth for the wind turbine system in the second position shown in Figure 9.
  • Figure 11 is a diagrammatic view of a tidal turbine system according to another embodiment of the present invention.
  • Figure 12 shows a sensing arrangement for use in the present invention
  • Figure 13 is a diagrammatic plan view of the tidal turbine system shown in Figure 1 1 , in a first position;
  • Figure 14 is a graph showing a plot of water speed against azimuth for the tidal turbine system in the first position shown in Figure 13;
  • Figure 15 is a diagrammatic plan view of the tidal turbine system shown in
  • Figure 1 1 , in a second position
  • Figure 16 is a graph showing a plot of water speed against azimuth for the tidal turbine system in the second position shown in Figure 15;
  • Figure 17 is a diagrammatic view of a turbine system according to another embodiment of the present invention.
  • FIG. 1 of the accompanying drawings shows a remote sensing device 10 according to a first embodiment of the present invention.
  • the remote sensing device 10 comprises a source S, an emitter E and a receiver R.
  • the source S includes a seed laser 12, an optical splitter 14, an acousto-optic modulator (AOM) 16, a pulsed optical amplifier 18 and an optical circulator 20.
  • the seed laser 12 is coupled to the optical splitter 14 by a first connector in the form of optical fibre 22.
  • the optical splitter 14 is coupled to the AOM 16 by a connector in the form of optical fibre 24.
  • the AOM 16 is coupled to the optical amplifier 18 by a connector in the form of optical fibre 26.
  • the optical amplifier 18 is coupled to the optical circulator 20 by a connector in the form of optical fibre 28.
  • the emitter E includes a horizontal array of optical telescopes 30 (three optical telescopes 30 are shown in the embodiment of Figure 1), each of which in the illustrated embodiment is independently connected to the optical circulator 20 in the source S by means of an optical switch 32 and connectors in the form of optical fibres 34.
  • the optical switch 32 is coupled to the optical circulator 20 via a connector in the form of optical fibre 36.
  • the receiver R includes a detector 38 and an analogue-to-digital converter 40 via a connector in the form of optical fibre 42, which in turn is interfaced to a digital processing system 44 via a connector in the form of optical fibre 46.
  • the detector 38 is connected to the optical splitter 14 by a connector in the form of optical fibre 48 and is connected to the optical circulator 20 by a connector in the form of optical fibre 50.
  • the optical fibres 22, 24, 26, 28, 34, 36, 42, 46 and 48 comprise standard optical fibres and the optical fibre 50 comprises a polarisation maintaining optical fibre.
  • the optical fibres 22, 24, 26, 28, 34, 36, 42, 46 and 48 may alternatively comprise polarisation maintaining optical fibre and the optical fibre 50 may comprise a standard optical fibre if required.
  • embodiments of the present invention may beneficially apply the principles of spectroscopy to directly detect the Doppler (frequency) shift.
  • the range of frequencies of the reflected (return) signal onto which this frequency shift has been imparted may be analysed using filters to selected and compare the return signal at specific frequency values and the Doppler shift may be inferred from this comparison.
  • the remote sensing device 10 may in particular embodiments have a pulsed mode of operation in which a short burst of radiation is emitted and the return signal is then chronologically recorded. Where the emitted radiation has a constant speed of propagation in the atmosphere, the return signal can be processed according to the elapsed time from pulse emission to determine the range from the device from which the signal was returned.
  • the seed laser 12 In operation, the seed laser 12 generates a narrow linewidth continuous wave laser signal with high frequency stability.
  • the frequency shift of the return signal is small compared to the frequency of the emitted signal so a narrow line-width and high stability is required to enable the accurate detection of particle speed.
  • the output of the seed laser 12 is coupled into the input of the AOM 16 via the optical fibre 22.
  • a portion of the signal output by the seed laser 12 is fed into the separate optical fibre 48 at this stage using the optical splitter 14.
  • This provides a reference signal that is feed into the detector 38 to be mixed with the return signal.
  • the AOM 16 has a dual function with respect to the processing of the signal to be emitted from the device 10. Firstly, it controls the amplitude of the incoming signal from the seed laser 12, applying a pulse profile to enable return signal range to be determined. Secondly, it applies a constant stable frequency offset to the signal from the seed laser 12 that enables the detector 38 to determine whether the frequency of the return signal is higher than or lower than that of the emitted signal. Beneficially, this enables the device 10 to detect whether the particles are moving towards or away from the emitter E.
  • the output of the AOM 16 is fed into the pulsed optical amplifier 18.
  • the optical amplifier 18 increases the power of the optical signal such that the emitted radiation is capable of propagating to the desired measurement range and being detected on return.
  • optical switch 32 The output of the optical amplifier 18 is fed via optical fibre 26 through an optical circulator 20 and in the embodiment illustrated in Figure 1 is connected to optical switch 32. Beyond the optical circulator 20, that is in the emitter E, the emitted and received signals share the same optical path.
  • the optical circulator 20 acts as a splitter separating the emitted and returned signals by means of their polarisation and feeding the return signal into the detector 38 by means of the polarisation maintaining optical fibre 50.
  • the optical switch 32 is connected to the array of optical telescopes through the separate optical fibres 34. The optical switch 32 can be instructed to make a connection between the optical circulator 20 and each of the N optical telescopes 30 in isolation.
  • the remote sensing device 10' comprises a source S', an emitter E' and a receiver R'.
  • the source S' includes a seed laser 12', an optical splitter 14', an acousto-optic modulator (AOM) 16', a pulsed optical amplifier 18' and an optical circulator 20'.
  • the seed laser 12' is coupled to the optical splitter 14' by a first connector in the form of optical fibre 22'.
  • the optical splitter 14' is coupled to the AOM 16' by a connector in the form of optical fibre 24'.
  • the AOM 16' is coupled to the optical amplifier 18' by a connector in the form of optical fibre 26'.
  • the optical amplifier 18' is coupled to the optical circulator 20' by a connector in the form of optical fibre 28'.
  • the receiver R' includes a detector 38' and an analogue-to-digital converter 40' via a connector in the form of optical fibre 42', which in turn is interfaced to a digital processing system 44' via a connector in the form of optical fibre 46'.
  • the detector 38' is connected to the optical splitter 14' by a connector in the form of optical fibre 48' and is connected to the optical circulator 20' by a connector in the form of optical fibre 50'.
  • the emitter E' of the remote sensing device 10' comprises a scanning arrangement rather than an arrangement of telescopes connected to a switch.
  • the scanning arrangement comprises a single telescope 28' connected to a mirror or prism 44 whose orientation can be adjusted to emit and receive the emitted and returned signal along lines of sight with different azimuths.
  • Figure 3 is a side view of the scanning arrangement of the remote sensing device 10'.
  • the lidar beam is directed onto a mirror 50 whose orientation may be adjusted to scan the lidar beam through a range of azimuth angles.
  • the mirror 50 comprises a multifaceted prism or mirror which is rotated about an axis to scan the lidar beam through the range of azimuth angles.
  • Figure 4 is a plan view of the scanning system of the remote sensing device
  • the source S' is connected to the emitter E' where a telescope 30' expands and collimates the lidar beam and directs it onto the mirror 50 which reflects the beam through a right angle.
  • the mirror 50 is mounted on a scanning motor 52 that may rotate it about a single axis parallel with the optical axis of the telescope 30' to scan the reflected lidar beam through the range of azimuth angles.
  • Operation of the remote sensing device 10' is similar to that of the device 10 and as in the device 10, in the device 10' the detector 34' mixes the emitted and returned signals producing an interference signal that is digitized by the analogue-to- digital converter 36'.
  • the digitized signal is processed by the digital processing system 38' to provide an output, for example an estimate of the air speed along the line of sight (LoS) of the emitted beam of radiation.
  • LiS line of sight
  • the remote sensing devices 10, 10' described above may in particular embodiments be applied to the measurement of air speed and direction behind a wind power generator or may be applied to the measurement of water speed behind a tidal power generator, as described below with reference to Figures 5 to 17.
  • a horizontal array of optical telescopes 30 as described above with reference to Figure 1 or other emitter/receiver systems such as, for example, the scanning arrangement as described above with reference to Figures 2 to 4, is mounted facing rearward on the nacelle of a wind power generator (WPG) or to measure air speed or on the nacelle of a tidal power generator to measure water speed at points spanning the wake of the generator.
  • WPG wind power generator
  • the variation in the azimuth angle of the beam required for the detection of yaw error may be achieved using a scanning system, such as the scanning arrangement described above with reference to Figures 2, 3 and 4.
  • air speed differences across the wind power generator wake as measured by the invention may be applied to determine the orientation of the wind power generator with respect to the oncoming wind.
  • Information regarding the orientation of the wind power generator (WPG) with respect to the oncoming wind may be used to control the orientation of the (WPG) where the invention is permanently installed on the wind power generator (WPG) or to inform the calibration of direction sensors and associated systems used to control the orientation of the wind power generator (WPG) through temporary or permanent installation of the invention on or near the wind power generator (WPG).
  • FIG. 5 of the accompanying drawings there is shown a diagrammatic perspective view of a system according to an embodiment of the present invention.
  • the system comprises a wind turbine system.
  • the system may take other forms and may for example comprise a tidal energy capture turbine system or the like.
  • the wind turbine system comprises a wind turbine 1012 having a tower 1014, a nacelle 1016 and a hub 1018 having a plurality of radially extending blades 1020.
  • the hub 1018 is operatively coupled to an electrical generator 1022 via a drive shaft 1024.
  • a gear arrangement 1026 in the form of a gear box is provided, although in other embodiments a gear arrangement may not be provided.
  • the turbine 1012 further comprises a controller 1028, the controller 1028 operatively coupled to a yaw drive arrangement 1030 capable of adjusting the angle of the turbine 1012.
  • the kinetic energy of wind W as shown in Figure 7, impinging on the blades 1020 drives rotation of the hub 1018 relative to the nacelle 1016, this kinetic energy being transmitted via the drive shaft 1024 (and the gear arrangement 1026 where provided) to the electrical generator 1022 where it is converted into electricity.
  • the system further comprises a sensing arrangement 1032 which, in the illustrated embodiment, is disposed on the nacelle 1016 of the wind turbine 1012. It will be recognised, however, that the sensing arrangement 1032 may be provided at other suitable locations, such as a remote location, a platform, on the ground or on one or more other turbine.
  • the sensing arrangement 1032 may comprise the remote sensing device 10 or the remote sensing device 10' described above.
  • the sensing arrangement 1032 is configured to acquire air flow data from a downstream wake 1034 produced by the rotating blades 1020 of the wind turbine 1012.
  • the sensing arrangement 1032 comprises a Lidar unit 1035 having an optical source 1036 - 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 1034 produced by the blades 1020.
  • the unit 1035 further comprises or is operatively associated with a receiver 1038 - in the illustrated embodiment an optical antenna -for detecting the light reflected back from the wake 1034. 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.
  • the sensing arrangement 1032 acquires data relating to the air flow velocity in the wake 1034 across a three-dimensional flow field, which data is then processed to determine the relative angle of the wind turbine 1012 and the average direction D of the incident resource W as shown in Figure 7.
  • Figure 7 shows a plan view of the wind turbine system in a first position, in which the wind turbine 1012 is positioned at an angle ⁇ to the average direction D of the wind W.
  • the sensing arrangement 1032 is positioned at, or calibrated to, the rotational axis 1040 of the turbine 1012 and, in use, the sensing arrangement 1032 acquires wind speed and azimuth (of the lidar beam) data relative to the turbine axis 1032 by scanning a three-dimensional field which includes the wake 1034 produced by the blades 1020 of the turbine 1012, in the illustrated embodiment the scan represented by reference numeral 1042.
  • FIG 8. A graph showing a plot of the acquired wind speed and azimuth data for cross section A-A of wake 1034 when the turbine 1012 is in the first position is shown in Figure 8.
  • the wake 1034 produced by the blades 1020 of the turbine 1012 is deflected and a core 1044 of the wake 1034 - as represented in the graph by the lowest point - is out of alignment with the rotational axis 1040 of the turbine 1012, the azimuth a of the core 1044 relative to the turbine rotational axis 1040 corresponding to the misalignment of the turbine 1012 relative to the average direction of the incident resource D.
  • an output indicative of the misalignment of the turbine 1012 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 1012 from the position shown in Figure 7 to the position shown in Figure 9.
  • Figure 9 shows a plan view of the wind turbine system in the second position, in which the wind turbine 1012 is positioned in exact alignment with the rotational axis 1040 of the turbine 1012 and Figure 10 shows a graph showing a plot of the acquired wind speed and azimuth data for cross section B-B of wake 1034 when the turbine 1012 is in the second position.
  • the wake 1034 produced by the blades 1020 of the turbine 1012 is symmetrical about the turbine rotational axis 1040 and the core 1044 of the wake 1034 - as represented in the graph by the lowest point - is aligned with the rotational axis 1040 of the turbine 1012.
  • the system 1 1 10 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 such as an ADCP, although it will be recognised that other sensing arrangements may be used where appropriate.
  • Sodar Sound Detection and Ranging
  • the tidal turbine system 11 10 comprises a tidal turbine 1 112 having a tower 1 14, a nacelle 1 116 and a hub 1 118 having a plurality of radially extending blades 1120.
  • the hub 1 118 is operatively coupled to an electrical generator 1 122 via a drive shaft 1124.
  • a gear arrangement 1 126 in the form of a gear box is provided, although in other embodiments a gear arrangement may not be provided.
  • the turbine 11 12 further comprises a controller 1 128, the controller 1 128 operatively coupled to a yaw drive arrangement 1 130 capable of adjusting the angle of the turbine 1 112 in the body of water.
  • the kinetic energy of water impinging on the blades 1120 drives rotation of the hub 11 18 relative to the nacelle 1 116, this kinetic energy being transmitted via the drive shaft 1124 (and the gear arrangement 1126 where provided) to the electrical generator 1 122 where it is converted into electricity.
  • the system 1 110 further comprises a sensing arrangement 1 132 which, in the illustrated embodiment, is disposed on the nacelle 1 116 of the tidal turbine 1 112. It will be recognised, however, that the sensing arrangement 1 132 may be provided at other suitable locations, such as a remote location, a platform, on the seabed or on one or more other turbine.
  • the sensing arrangement 1132 may comprise the remote sensing device 10 described above with reference to Figure 1 or the remote sensing device 10' described above with reference to Figures 2 to 4.
  • the sensing arrangement 1 132 is configured to acquire flow data from a downstream wake 1 134 produced by the rotating blades 1 120 of the tidal turbine 1 112.
  • the sensing arrangement 132 comprises a Sodar unit 1 135 having a sound source 1136 for transmitting sound pulses over the desired flow field, which in embodiments of the invention comprises the downstream fluid wake 1 134 produced by the blades 1120.
  • the unit 1135 further comprises or is operatively associated with a receiver 1138 for detecting the sound reflected back from the wake 1 134.
  • 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.
  • the sensing arrangement 1132 acquires data relating to the flow velocity in the wake 1 134 across a three-dimensional flow field, which data is then processed to determine the relative angle of the wind turbine 11 12 and the average direction D' of the incident resource W.
  • Figure 13 shows a plan view of the tidal turbine system
  • the sensing arrangement 1 132 is positioned at, or calibrated to, the rotational axis 1140 of the turbine 1 1 12 and, in use, the sensing arrangement 1 132 acquires flow speed and azimuth data relative to the turbine axis 1 132 by scanning a three- dimensional field which includes the wake 1 134 produced by the blades 1 120 of the turbine 11 12, in the illustrated embodiment the scan represented by reference numeral 1 142.
  • FIG. 14 A graph showing a plot of the acquired flow speed and azimuth data for cross section C-C of wake 1 134 when the turbine 11 12 is in the first position is shown in Figure 14.
  • the wake 1134 produced by the blades 1120 of the turbine 11 12 is deflected and a core 1144 of the wake 1134 - as represented in the graph by the lowest point - is out of alignment with the rotational axis 1 140 of the turbine 11 12, the azimuth a' of the core 1 144 relative to the turbine rotational axis 1140 corresponding to the misalignment of the turbine 11 12 relative to the average direction of the incident resource D'.
  • an output indicative of the misalignment of the turbine 1 1 12 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 1 1 12 from the position shown in Figure 13 to the position shown in Figure 15.
  • Figure 15 shows a plan view of the tidal turbine system 11 10 in the second position, in which the tidal turbine 11 12 is positioned in exact alignment with the rotational axis 1140 of the turbine 11 12 and Figure 16 shows a graph showing a plot of the acquired flow speed and azimuth data for cross section D-D of wake 1134 when the turbine 11 12 is in the second position.
  • the wake 1 134 produced by the blades 1120 of the turbine 11 12 is symmetrical about the turbine rotational axis 1 140 and the core 1144 of the wake 1134 - as represented in the graph by the lowest point - is aligned with the rotational axis 1 140 of the turbine 1 1 12.
  • 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.
  • FIG 17 there is shown a system 1210 according to an alternative embodiment of the invention.
  • the system 1210 is similar to the systems 1010, 1 1 10 described above with the difference that the sensing arrangement 1232 is located on the ground.
  • the turbine system 1210 comprises a turbine 1212 having a tower 1214, a nacelle 1216 and a hub 1218 having a plurality of radially extending blades 1220.
  • the hub 1218 is operatively coupled to an electrical generator 1222 via a drive shaft 1224.
  • a gear arrangement 1226 in the form of a gear box is provided, although in other embodiments a gear arrangement may not be provided.
  • the turbine 1212 further comprises a controller 1228, the controller 1228 operatively coupled to a yaw drive arrangement 1230 capable of adjusting the angle of the turbine 1212.
  • the kinetic energy of incident resource for example air or water
  • the kinetic energy of incident resource drives rotation of the hub 1218 relative to the nacelle 1216, this kinetic energy being transmitted via the drive shaft 1224 (and the gear arrangement 1226 where provided) to the electrical generator 1222 where it is converted into electricity.
  • the sensing arrangement 1232 is disposed on the ground and is configured to acquire flow data from a downstream wake 1234 produced by the rotating blades 1220 of the turbine 1212.
  • the sensing arrangement 1232 itself may be of any suitable form and may, for example comprise a Lidar sensing arrangement such as the sensing arrangement 1 132 described above or a Sodar sensing arrangement such as the sensing arrangement 1132 described above, and the sensing arrangement 1 132 may comprise the remote sensing device 10 described above with reference to Figure 1 or the remote sensing device 10' described above with reference to Figures 2 to 4.
  • 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.
  • 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.
  • the sensing arrangement may be left in-situ for continuous application.

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Abstract

L'invention concerne un dispositif de détection à distance (10) destiné à être utilisé dans un système pour la correction du mauvais alignement de lacet d'un dispositif de capture d'énergie, tel qu'une turbine éolienne, une turbine marémotrice ou analogue. Ledit dispositif comprend une source (S), un émetteur (E) comprenant un réseau horizontal de télescopes optiques (30) indépendamment connectés à un circulateur optique (20) dans la source (S) au moyen d'un commutateur optique (32) ou un dispositif de balayage comprenant un seul télescope (28') connecté à un miroir ou prisme (44) dont l'orientation peut être ajustée pour émettre et recevoir le signal émis et renvoyé le long de lignes de visée avec différents azimuts. Un récepteur (R) comprend un détecteur (38) et un convertisseur analogique-numérique (40), qui est interfacé à un système de traitement numérique (44).
PCT/GB2016/052626 2015-08-24 2016-08-24 Dispositif de détection à distance WO2017033009A1 (fr)

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WO2008052365A1 (fr) * 2006-10-30 2008-05-08 Autonosys Inc. Système de balayage pour un lidar
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CN109100534A (zh) * 2018-05-24 2018-12-28 远景能源（江苏）有限公司 一种多角度测风设备及其运行方法
CN115508853A (zh) * 2022-11-04 2022-12-23 青岛镭测创芯科技有限公司 一种测速装置、激光测速方法、系统及介质
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