• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    method and system for controlling a wind turbine and method for identifying a surface condition of a rotor blade of a wind turbine in one aspect, a method for controlling a wind turbine based on an identified condition of a surface of a blade of the rotor may include monitoring a wind turbine operating parameter to obtain parameter data related to the operating parameter when a wind turbine operating input changes, analyzing the parameter data to identify a rotor blade roughness state, and taking action. correction in response to the identified roughness state.
    公开号:BR102014003222B1
    申请号:R102014003222-3
    申请日:2014-02-11
    公开日:2022-01-11
    发明作者:Andreas HERRIG；Saskia Gerarda Honhoff
    申请人:General Electric Company；
    IPC主号:
    专利说明:

    FIELD OF THE INVENTION
    [001] The present invention relates generally to wind turbines and, more particularly, to a system and method for controlling a wind turbine based on identified conditions of the surface of the rotor blades. BACKGROUND OF THE INVENTION
    [002] Generally, a wind turbine includes a tower, a nacelle mounted on the tower, and a rotor attached to the nacelle. The rotor typically includes a rotating hub and a plurality of rotor blades coupled to and extending outward from the hub. Each rotor blade can be spaced around the hub to facilitate turning the rotor to allow kinetic energy to be transferred from the wind to usable mechanical energy, and subsequently, electrical energy.
    [003] During the operation of a wind turbine, the outer surface of the rotor blades often gets dirty or rough over time. For example, dust, pollen, insects, and/or other debris can often collect along the other surface of a rotor blade, particularly adjacent to the leading edge of the rotor blade. Additionally, various deposits can often form along the outer surface of a rotor blade, such as salt crystals, ice and/or the like, which thus have a roughening effect on the rotor blades. In addition, surface roughness of rotor blades can also be caused due to erosion (e.g. sand erosion) and other blade damage (e.g. bird impact damage), as well as due to manufacturing defects. .
    [004] When rotor blades become aerodynamically rough due to dirt and/or other factors, the amount of energy generated by the wind turbine (and therefore its Annual Energy Production (AEP)) is significantly reduced. This is primarily due to reduced blade performance (e.g., reduced climb characteristics, increased drag, earlier stopping, etc.) that result when increased surface roughness causes the transition point from laminar flow to turbulent flow through the blade. of the rotor to move upstream towards the leading edge, which additionally results in increased wall shear and boundary layer thickness. In addition to this reduction in performance, the increased surface roughness can also result in a significant increase in the amount of noise generated by the rotor blades.
    [005] Accordingly, a system and method for controlling a wind turbine in response to identified blade surface conditions (e.g., increased surface roughness) that allows a wind turbine AEP to be increased and/or the amount of noise generated by rotor blades is reduced despite the presence of aerodynamically rough blade surfaces are welcome to the technology. DESCRIPTION OF THE INVENTION
    [006] Aspects and advantages of the invention will be enumerated in part in the following description, or may be obvious from the description, or may be learned through practice of the invention.
    [007] In one aspect, the present invention is directed to a method for controlling a wind turbine based on an identified condition of a surface of a wind turbine rotor blade. The method may generally include monitoring a wind turbine operating parameter to obtain parameter data related to the operating parameter when a wind turbine operating input changes, analyzing the parameter data to identify a rotor blade roughness state, and performing a corrective action in response to the identified roughness state.
    [008] In another aspect, the present invention is directed to a method for identifying a surface condition of a rotor blade of a wind turbine. The method may generally include tuning an operating input of the wind turbine, monitoring an operating parameter of the wind turbine to obtain parameter data related to the operating parameter when the operating input is adjusted, and analyzing the parameter data to identify a roughness state of the wind turbine. rotor blade.
    [009] In a further aspect, the present invention is directed to a system for controlling a wind turbine based on an identified condition of a surface of a wind turbine rotor blade. The system may generally include a sensor configured to monitor a wind turbine operating parameter when a wind turbine operating input changes and a controller communicatively coupled to the sensor to thereby obtain parameter data related to the operating parameter. The controller can be configured to analyze parameter data to identify a rotor blade roughness state. Additionally, the controller can be configured to take corrective action in response to the identified roughness state.
    [010] These and other features, aspects and advantages of the present invention will be better understood with reference to the following description and appended claims. The accompanying drawings, which are incorporated and constitute a part of this specification, illustrate embodiments of the invention and, together with the description, serve to explain the principles of the invention. BRIEF DESCRIPTION OF THE DRAWINGS
    [011] A complete and enabling disclosure of the present invention, including the best mode thereof, addressed to a person skilled in the art, is presented in the specification, which makes reference to the attached figures.
    [012] FIGURE 1 illustrates a perspective view of a wind turbine embodiment.
    [013] FIGURE 2 illustrates a simplified internal view of a form of a nacelle of a wind turbine.
    [014] FIGURE 3 illustrates a schematic diagram of a modality of suitable components that can be included within a wind turbine controller.
    [015] FIGURE 4 illustrates a flowchart of an embodiment of a method for controlling a wind turbine in response to identified rotor blade surface conditions in accordance with aspects of the present invention.
    [016] FIGURE 5 provides a graphical representation of an example of how parameter data can be obtained for a wind turbine operating parameter when a wind turbine operating input changes.
    [017] FIGURE 6 provides a graphical representation of an example of data compilation for a plurality of data sets that map the dynamic response of a particular operational parameter to change in a specific operational input to clean rotor blades aerodynamically.
    [018] FIGURE 7 provides a graphical representation of an example of data compilation for a plurality of data sets that map the dynamic response of a particular operational parameter to change in a specific operational input to aerodynamically rough rotor blades.
    [019] FIGURE 8 provides a graphical representation of the average trend lines for the data compilation example shown in FIGURES 6 and 7.
    [020] FIGURE 9 illustrates a perspective view of a rotor blade that has various modalities of surface roughness sensors installed on it. DESCRIPTION OF EMBODIMENTS OF THE INVENTION
    [021] Reference will now be made in detail to embodiments of the invention, one or more examples of which are illustrated in the drawings. Each example is provided by way of explanation of the invention, not limitation of the invention. Indeed, it will be apparent to one skilled in the art that various modifications and variations can be made to the present invention without departing from the scope or spirit of the invention. For example, features illustrated or described as part of one embodiment can be used with another embodiment to produce a still additional embodiment. Therefore, it is understood that the present invention covers these modifications and variations as they fall within the scope of the appended claims and their equivalents.
    [022] In general, the present invention is directed to a system and method for controlling a wind turbine in response to identified conditions on the surface of rotor blades. Specifically, in some embodiments, the present invention is directed to a method for indirectly detecting a roughness state of the rotor blades and, based on that roughness state, controlling the wind turbine to accommodate any surface roughness of the rotor blades. For example, multiple sensors can be used to monitor one or more operating parameters of the wind turbine (e.g. shaft bending, blade bending, tower bending, power, generator speed, generator torque, tower/hub vibration / blade, blade noise and/or the like) when one or more wind turbine operating inputs (e.g. pitch angle, rotation angle, generator speed, generator torque, wind conditions such as wind speed and/or wind condition) are actively adjusted or otherwise changed. As such, the dynamic response of operating parameters to changes in operating inputs can be monitored to allow a significant amount of parameter data to be obtained for each combination of operating parameter(s) / operating input(s) . For example, parameter data for a particular parameter(s)/input(s) combination may initially be obtained when it is known or anticipated that the rotor blades are aerodynamically clean, which may allow this clean parameter data to be used as a baseline for analyzing data obtained subsequently. Specifically, when additional parameter data for the particular parameter(s) / input(s) combination is obtained, it can be compared to the cleared parameter data. If the new parameter data differs from the clean parameter data by a significant amount (e.g. beyond an acceptable limit), it can be assumed or determined that the blades have changed from an aerodynamically clean state to an aerodynamically rough state due to dirt. , erosion, blade damage, etc. In this case, appropriate corrective action can be taken (e.g. tilting the rotor blades and/or modifying the generator operation) to optimize the wind turbine operation for the current roughness state of the rotor blades, in order to allow the overall performance of the wind turbine to be improved.
    [023] It should be appreciated that, as used in this document, the term “aerodynamically clean” may refer to a surface condition for a rotor blade in which there is no surface roughness (i.e., an aerodynamically smooth blade) and / or for a surface condition in which, although there is some surface roughness on the rotor blade, it is not sufficient to have a significant impact on blade performance (e.g. in cases where only a small part of the blade surface is blade is rough and/or when surface variations across the blade surface are less than a given amount, such as less than 0.5 millimeter). Similarly, the term “aerodynamically rough” can refer to a surface condition for a rotor blade in which the surface roughness on the blade is sufficient to have a significant impact on blade performance and, therefore, the blade surface. rotor can no longer be considered aerodynamically clean.
    [024] Now with reference to the drawings, FIGURE 1 illustrates a perspective view of an embodiment of a wind turbine 10. As shown, the wind turbine 10 generally includes a tower 12 that extends from a supporting surface. 14, a nacelle 16 mounted to the turret 12, and a rotor 18 coupled to the nacelle 16. The rotor 18 includes a rotating hub 20 and at least one rotor blade 22 coupled to and extending outwardly from the hub 20. For example , in the illustrated embodiment, rotor 18 includes three rotor blades 22. However, in an alternative embodiment, rotor 18 may include more or less than three rotor blades 22. Each rotor blade 22 may be spaced around the hub 20 to facilitate rotation of rotor 18 to allow kinetic energy to be transferred from the wind into usable mechanical energy, and subsequently, electrical energy. For example, the hub 20 may be rotatably coupled to an electrical generator 24 (FIGURE 2) positioned within the nacelle 16 to allow electrical power to be produced.
    [025] The wind turbine 10 may also include a turbine control system or turbine controller 26 centered within the nacelle 16. In general, the controller 26 may comprise a computer or other suitable processing unit. Therefore, in some embodiments, controller 26 may include suitable computer-readable instructions that, when implemented, configure controller 26 to perform various different functions, such as receiving, transmitting, and/or executing wind turbine control signals. As such, controller 26 may be configured generally to control the various operating modes (e.g., start-up or shutdown sequences) and/or components of wind turbine 10. For example, controller 26 may be configured to adjust the pitch or blade pitch angle of each rotor blade 22 (i.e., an angle that determines a perspective of blade 22 with respect to wind direction) around its pitch axis 28 in order to control the rotational speed of the rotor blade. rotor 22 and/or the power output generated by wind turbine 10. Specifically, in some embodiments, controller 26 may control the pitch angle of rotor blades 22, either individually or simultaneously, transmitting suitable control signals directly or indirectly (e.g. via a tilt controller 30 (FIGURE 2)) to one or more tilt adjustment mechanisms 32 (FIGURE 2) of wind turbine 10. In a similar manner, the controller 26 can be configured to adjust the angle of rotation of the nacelle 16 (i.e., an angle that determines a perspective of the nacelle 16 relative to the wind direction) around a geometric axis of rotation 34 of the wind turbine. 10. For example, controller 26 may transmit suitable control signals to one or more rotation drive mechanisms 36 (FIGURE 2) of wind turbine 10 to automatically control the angle of rotation.
    [026] Now with reference to FIGURE 2, a simplified internal view of an embodiment of the nacelle 16 of the wind turbine 10 shown in FIGURE 1 is illustrated. As shown, a generator 24 may be arranged within the nacelle 16. In general, the generator 24 may be coupled to rotor 18 to produce electrical power from rotational energy generated by rotor 18. For example, as shown in the illustrated embodiment, rotor 18 may include a rotor shaft 38 coupled to hub 20 for rotation therewith. . The rotor shaft 38 may, in turn, be rotatably coupled to a generator shaft 40 of the generator 24 via a gearbox 42. As is generally understood, the rotor shaft 38 may provide both low-speed and high-speed input. torque to the gearbox 42 in response to rotation of the rotor blades 22 and hub 20. The gearbox 42 can then be configured to convert the low-speed, high-torque input to a high-speed, low-torque output for drive the generator shaft 40 and hence the generator 24.
    [027] Additionally, as indicated above, controller 26 can also be located inside nacelle 16 (eg inside a box or control panel). However, in other embodiments, controller 26 may be located within any other component of wind turbine 10 or at a location outside the wind turbine (e.g., when controller 26 is configured as a group controller to control a plurality of of wind turbines). As is generally understood, controller 26 may be communicatively coupled to any number of components of wind turbine 10 in order to control the operation of these components. For example, as indicated above, controller 26 can be communicatively coupled to each pitch adjustment mechanism 32 of wind turbine 10 (one for each rotor blade 22) via a pitch controller 30 to facilitate rotation of each blade. of the rotor 22 around its tilt axis 28.
    [028] In general, each tilt adjustment mechanism 32 may include any suitable components and may have any suitable configuration that allows the tilt adjustment mechanism 32 to function as described in this document. For example, in some embodiments, each tilt adjustment mechanism 32 may include a tilt drive motor 44 (e.g., any suitable electric motor), a tilt drive gearbox 46, and a tilt drive pinion. 48. In these embodiments, the tilt drive motor 44 can be coupled to the tilt drive gearbox 46 so that the tilt drive motor 44 transmits mechanical force to the tilt drive gearbox 46. similarly, the tilt drive gearbox 46 can be coupled to the tilt drive pinion 48 to rotate with it. Tilt drive pinion 48 may in turn be in operational engagement with tilt bearing 50 coupled between hub 20 and a corresponding rotor blade 22 such that rotation of tilt drive pinion 48 causes bearing rotation. 50. Therefore, in these embodiments, rotation of the tilt drive motor 44 drives the tilt drive gearbox 46 and the tilt drive pinion 48, to thereby rotate the tilt bearing 50 and the blade of the tilt drive. rotor 22 around the tilt axis 28.
    [029] In alternative embodiments, it should be appreciated that each pitch adjustment mechanism 32 may have any other suitable configuration that facilitates the rotation of a rotor blade 22 around its pitch axis 28. For example, it is known that the tilt adjustment mechanisms 32 include a hydraulic or pneumatic drive device (e.g., a hydraulic or pneumatic cylinder) configured to transmit rotational energy to the tilt bearing 50 to thereby cause the rotor blade 22 to rotate in around its tilt axis 28. Therefore, in some embodiments, in place of the tilt drive electric motor 44 described above, each tilt adjustment mechanism 32 may include a hydraulic or pneumatic drive device that utilizes fluid pressure to apply torque to the tilt bearing 50.
    [030] The wind turbine 10 may also include one or more rotation drive mechanisms 36 to adjust the angle of rotation of the nacelle 16. In some embodiments, similar to the pitch adjustment mechanisms 32, each rotation drive mechanism 36 may include a spin drive motor 52 (e.g., any suitable electric motor), a spin drive gearbox 54, and a spin drive pinion 56 coupled together for simultaneous rotation. However, in other embodiments, each rotation drive mechanism 36 may have any other suitable configuration, such as being hydraulically or pneumatically driven. Independently, the rotation drive mechanism(s) 36 may be configured to adjust the angle of rotation by rotationally engaging the rotation drive pinion 56 with a suitable rotation bearing 58 (also referred to as a slewing ring gear or turret ring gear) of the wind turbine 10, to thereby allow the nacelle 16 to be rotated about the axis of rotation 34 (FIGURE 1) relative to the wind.
    [031] It should be appreciated that, by controlling the various components of the wind turbine 10, the controller 26 can be configured to automatically adjust the operation of the wind turbine 10. For example, as indicated above, the controller 26 can be configured to transmit suitable control signals to pitch adjustment mechanisms 32 (via pitch controller 30) to automatically adjust pitch angle of rotor blades 22. Similarly, controller 26 can be configured to transmit suitable control signals to the rotation drive mechanism(s) 36 to allow the angle of rotation of the nacelle 16 to be automatically adjusted. Additionally, controller 26 may be communicatively coupled to various other wind turbine components in order to control different aspects of wind turbine operation. For example, controller 26 may be communicatively coupled to generator 24 to allow automatic adjustment of generator torque, generator speed, and/or any other suitable operational aspects of generator 24.
    [032] Additionally, the wind turbine 10 may also include one or more sensors to monitor various operating parameters of the wind turbine 10. For example, in some embodiments, the wind turbine 10 may include one or more configured axis sensors 60. to monitor one or more operating parameters related to the wind turbine shaft 10, such as the actuation of loads on the rotor shaft 38 (e.g. thrust, bending and/or torque loads), the deflection of the rotor shaft 38 ( e.g. including shaft bending), the rotational speed of the rotor shaft 38 and/or the like. Therefore, suitable axis sensors 60 may include, for example, one or more load sensors (e.g. strain gauge, pressure sensors), optical sensors (e.g. proximity sensors, laser sensors, fiber optic sensors, cameras, LIDAR sensors), radar sensors, accelerometers, magnetic sensors, speed sensors, Micro Inertial Measurement Units (MIMUs) and/or the like.
    [033] The wind turbine 10 may also include one or more blade sensors 62 (FIGURES 1 and 2) configured to monitor one or more operating parameters related to the blades of the wind turbine 10, such as the actuation of loads on the blades 22 (e.g. bending loads), deflection of blades 22 (e.g. including bending, blade twisting and/or the like), vibration of blades 22, noise generated by blades 22, angle of inclination of blades 22 , the rotational speed of the blades 22 and/or the like. Therefore, suitable blade sensors 62 may include, for example, one or more load sensors (e.g. strain gauge, pressure sensors), optical sensors (e.g. proximity sensors, laser sensors, fiber optic sensors, cameras and LIDAR sensors), radar sensors, accelerometers, magnetic sensors, speed sensors, angle of attack sensors, vibration sensors, noise sensors (e.g. microphones), Micro Inertial Measurement Units (MIMUs) and/or the like . As will be described below with reference to FIGURE 9, rotor blades 22 may also include one or more roughness sensors 200, 202, 204 configured to directly monitor the surface roughness of blades 22.
    [034] Additionally, the wind turbine 10 may include one or more generator sensors 64 configured to monitor one or more operating parameters related to the wind turbine generator 10, such as the power output of the generator 24, the rotational speed of the generator 24, generator torque and/or the like. Therefore, suitable generator sensors 64 may include, for example, power sensors (e.g. voltage sensors, current sensors), torque sensors, speed sensors and/or the like.
    [035] In addition, the wind turbine 10 may also include various other sensors to monitor various other turbine operating parameters. For example, as shown in FIGURE 2, the wind turbine 10 may include one or more tower sensors 66 (e.g., a load sensor(s), such as a strain gauge(s), accelerometer(s), MIMU() s), etc.) to monitor various operating parameters related to the tower, such as the actuation of the loads on the tower 12, the deflection of the tower 12 (e.g. bending and/or torsion of the tower), tower vibrations and/or the like . Additionally, the wind turbine 10 may include one or more wind sensors 68 (e.g., an anemometer(s)) to monitor one or more wind conditions of the wind turbine 10, such as wind speed and/or wind direction. Similarly, the wind turbine 10 may include one or more hub sensors 70 (e.g., a load sensor(s), accelerometer(s), etc.) to monitor various hub-related operating parameters (e.g., loads transmitted through hub 20, hub vibrations and/or the like) and/or one or more nacelle sensors 72 (e.g. a load sensor(s), accelerometer(s), etc.) to monitor one or more more operational parameters related to the nacelle (e.g. loads transmitted through nacelle 16, nacelle vibrations and/or the like). Naturally, the wind turbine 10 may additionally include various other sensors suitable for monitoring any other suitable operating parameters of the wind turbine 10. It should be appreciated that the various sensors described in this document may correspond to pre-existing sensors of a wind turbine 10. and/or sensors that have been specifically installed within the wind turbine 10 to allow one or more operating parameters to be monitored.
    [036] It should also be appreciated that, as used in this document, the term “monitor” and variations thereof indicate that the various sensors of the wind turbine 10 can be configured to provide a direct measurement of the operating parameters that are monitored or a measurement indirect way of these operational parameters. Therefore, the sensors can, for example, be used to generate signals related to the operating parameter being monitored, which can then be used by the controller 26 to determine the actual operating parameter.
    [037] Referring now to FIGURE 3, a block diagram of an embodiment of suitable components that may be included in the turbine controller 26 (and/or the tilt controller 30) in accordance with aspects of the present invention is illustrated. As shown, controller 26 may include one or more processor(s) 74 and associated memory device(s) 76 configured to perform a variety of computer-implemented functions (e.g., perform methods, steps, , calculations and the like disclosed in this document). As used herein, the term "processor" refers not only to integrated circuits referred to in the art as being included in a computer, but also refers to a controller, a microcontroller, a microcomputer, a programmable logic controller (PLC), a application-specific integrated circuit, and other programmable circuits. Additionally, memory device(s) 76 may generally comprise memory element(s) including, but not limited to, computer-readable media (e.g., random-access memory (RAM)), human-readable non-volatile media by computer (for example, a flash memory), a floppy disk, a read-only compact disk memory (CD-ROM), a magneto-optical disk (MOD), a digital versatile disk (DVD), and/or other elements adequate memory. This memory device(s) 76 can generally be configured to store suitable computer-readable instructions which, when implemented by the processor(s) 74, configure(s) the controller 26 to perform various functions including, but not limited to, monitoring one or more operating parameters of the wind turbine 10 based on signals received from sensors 60, 62, 64, 66, 68, 70, 72, transmit control signals suitable for implementing action corrections in response to identifying aerodynamically rough rotor blades 22 and various other suitable computer-implemented functions.
    [038] Additionally, the controller 26 may also include a communications module 78 to facilitate communications between the controller 26 and the various components of the wind turbine 10. For example, the communications module 78 may serve as an interface to allow turbine controller 26 transmits control signals to each pitch adjustment mechanism 32 to control the pitch angle of rotor blades 22. In addition, communications module 78 may include a sensor interface 80 (e.g., one or plus analog-to-digital converters) to allow signals transmitted from sensors 60, 62, 64, 66, 68, 70, 72 to be converted into signals that can be understood and processed by processors 58.
    [039] It should be appreciated that sensors 60, 62, 64, 66, 68, 70, 72 may be communicatively coupled to communications module 78 using any suitable means. For example, as shown in FIGURE 3, sensors 60, 62, 64, 66, 68, 70, 72 are coupled to sensor interface 80 via a wired connection. However, in other embodiments, sensors 60, 62, 64, 66, 68, 70, 72 may be coupled to sensor interface 64 over a wireless connection, such as using any suitable wireless communications protocol known in the art.
    [040] Referring now to FIGURE 4, a flowchart of an embodiment of a method 100 for controlling a wind turbine 10 based on an identified condition of a surface of a rotor blade 22 in accordance with aspects of the present invention is illustrated. In general, method 100 may allow surface roughness of rotor blades 22 to be detected indirectly by monitoring one or more operating parameters of the wind turbine (e.g. shaft deflection, blade deflection, tower deflection, power output , generator speed, generator torque, blade/hub/turret vibration, blade noise, derived from any operating parameters such as derived from generator speed and/or torque, and/or the like). The identified surface roughness can then be used as a basis for taking corrective actions to modify the wind turbine's operation to accommodate the current state of roughness of the rotor blades 22. For example, when the surface of the blades becomes roughened aerodynamically due to dirt, erosion, damage, etc., various aerodynamic properties of rotor blades 22, such as pitch coefficient, drag coefficient, pitch to drag ratio, stall angle, etc., are impacted, which can, in turn, cause variations in the operating parameters of the wind turbine. 10. Therefore, by monitoring one or more operating parameters of the wind turbine, surface roughness or lack thereof can be detected by identifying certain changes in operating parameters. As a result of detecting a given amount of surface roughness, the wind turbine's operation can be modified (e.g., by adjusting the pitch angle and/or tip speed ratio of the rotor blades) to reduce the impact of this harshness in the overall performance of the turbine.
    [041] As shown in FIGURE 4, at 102, one or more operating parameters of the wind turbine 10 can be monitored as one or more operating inputs of the turbine shift, to thereby allow parameter data corresponding to the dynamic response to be obtained. from the operational parameter(s) to change in the operational input(s). As used in this document, the term "operational input" refers to any suitable operational variable of a wind turbine 10 which, when varied, results in a change in one or more of the operational parameters of the wind turbine 10. For example, the operational inputs may include, but are not limited to, inputs that may be actively or automatically controlled, such as the pitch angle of rotor blades 22, the angle of rotation of the nacelle 16, the rotational speed of one or more turbine components 10 (e.g. rotor speed or generator speed), generator torque and/or the like, and various other operational inputs such as wind conditions (e.g. wind speed and/or wind direction).
    [042] In some embodiments, one or more of the operating inputs may be actively adjusted (e.g., actively tilting rotor blades 22, nacelle rotation 16, and/or controlling the operating speed and/or torque of generator 24) while one or more operating parameters are being monitored using the various sensors 60, 62, 64, 66, 68, 70, 72 described above to allow parameter data related to the operating parameter(s) to be obtained. Alternatively, for passive operational inputs (e.g. wind speed and/or wind direction), the operational parameter(s) can simply be monitored while this input(s) s) are changed to obtain parameter data related to the operational parameter(s). Independently, parameter data obtained from sensors 60, 62, 64, 66, 68, 70, 72 can then be transmitted to controller 26 for subsequent analysis and/or storage. It should be appreciated that, in some embodiments, parameter data may be obtained while the wind turbine 10 is operating.
    [043] FIGURE 5 provides a graphical representation of an example of how parameter data can be obtained when one of the operating inputs of the wind turbine 10 is changed or otherwise changes (e.g. in this case the tilt angle of the rotor blades 22). As shown, rotor blades 22 may be periodically tilted through one or more PAR1, PAR2 pitch angle intervals (e.g. tilting blades 22 away from the power position by a given angle, such as 5 to 15 degrees , holding the blades 22 at this angle for a given period of time and then tilting the blades 22 back to the power position) while one or more operating parameters are being monitored. This periodic tilting of the rotor blades 22 can allow multiple parameter data sets (e.g., a first data set (DS1), a second data set (DS2), . . . and an nth data set, in where N is the total amount of data sets obtained) are obtained over a plurality of separate time periods (e.g. TP1, TP2, TPN). For example, blades 22 may be tilted every minute, hourly, daily, weekly, monthly and/or any other suitable interval to allow a plurality of different sets of data to be obtained for each monitored operating parameter. Also, as shown in FIGURE 5, tilting the rotor blades 22 through two or more different pitch angle ranges PAR1, PAR2, the data sets may be representative of the different responses of the operating parameter(s). (s) to vary the magnitudes of change in tilt angle.
    [044] It should be appreciated that parameter data can be obtained in a similar way when changes are taking place in any other suitable operational input(s), for example, the angle of rotation of nacelle 16 can be periodically adjusted through a range of rotation angles while one or more of the operating parameters are being monitored. Similarly, generator speed and/or torque can be periodically adjusted across a range of speeds/torques to allow parameter data to be obtained for one or more of the operating parameters. Additionally, for changes in wind speed and/or wind direction, the operating parameter(s) can be monitored when wind speed and/or wind direction changes to allow parameter data to be obtained.
    [045] The parameter data obtained can then be organized and stored within the controller 26 and/or any other suitable data storage device. In some embodiments, the data sets obtained for a particular operating parameter in response to change in a specific operating input may be organized into a data compilation based on the observed, anticipated and/or known roughness state of the rotor blades 22. Specifically, there may be cases where it is known or anticipated that the rotor blades 22 are aerodynamically clean. For example, it can be assumed that the rotor blades 22 are aerodynamically clean when the blades 22 are new (or relatively new) or after the blades have been cleaned (e.g. after a storm or after the blades have been washed as part of of a maintenance operation). Parameter data obtained during these cases may be identified as "clean parameter data" and consequently may be stored within the controller 26 (or other storage device). As will be described below, this clean parameter data can then be used as baseline or reference data to detect changes in the surface roughness of the rotor blades.
    [046] For example, FIGURE 6 provides a graphical representation of an example of data compilation for a plurality of data sets (eg DS1, DS2 . . . DSN) that map the dynamic response of a particular operational parameter to change in a specific operational input (eg pitch angle) while rotor blades are aerodynamically clean. As shown, the obtained clean parameter data may be scattered due to sensor errors, variations in input magnitude changes (eg PAR1 v. PAR2), variations in other wind turbine operating parameters 10, and/or due to any other suitable factors. Therefore, in some embodiments, parameter data may be analyzed to determine a best fit or trend line corresponding to the average response in the relevant operating parameter as a result of variations in operating input. This trendline 100 for the cleaned parameter data can then, in some embodiments, serve as the basis for analyzing subsequently obtained parameter data to determine the roughness state of the rotor blades 22.
    [047] As indicated above, parameter data for the operational parameter(s) may be periodically obtained over a plurality of time periods (different eg TP1, TP2, TPN). Therefore, in addition to obtaining clean parameter data, parameter data can also be obtained when the roughness state of the rotor blades 22 is unknown and, in particular, when the surfaces of the rotor blades 22 are significantly roughened over time. For example, FIGURE 7 provides a graphical representation of an example of data compilation for a plurality of data sets (e.g. DS1, DS2 . . . DSN) that map the dynamic response of a particular operational parameter to change in a specific operational input (e.g. pitch angle) when the blade surfaces of rotor 22 are aerodynamically rough. As shown, similar to clean parameter data, this “rough parameter data” can be scattered due to sensor errors, variations in operating parameters and/or the like. Therefore, the data can be analyzed to determine a best fit or trend line 112 corresponding to the average response on the relevant operational parameter as a result of variations in operational input.
    [048] It should be appreciated that, in one embodiment, the surface of rotor blades 22 may be intentionally rough to allow baseline or reference data to be obtained for aerodynamically rough rotor blades 22. For example, a modifier of roughness (e.g., a turbulence strip) may be attached to the surface of the rotor blades 22 to allow reference data to be obtained for the blades 22.
    [049] It should also be appreciated that, for certain operational parameters, the measured parameter data may be dependent on wind speed and/or air density (eg wind speed times the air density squared). Therefore, for these operating parameters, the parameter data can be organized in the controller 26 based on the wind speed present at the time the data was collected. For example, parameter data can be grouped or stored within specific wind speed bands (e.g. with each wind speed band having a width of around 0.5 m/s to around 1 m/s ). Additionally, stored parameter data can also be corrected or normalized based on the actual air density present at the time the data was collected to allow the data to be comparable.
    [050] Again with reference to FIGURE 4, at 104, the parameter data obtained at 102 can be analyzed to identify a rotor blade roughness state. As indicated above, in some embodiments, the roughness state of rotor blades 22 can be identified by comparing recently or recently obtained parameter data to a baseline set of pre-stored clean parameter data. Therefore, to provide an example, it can be assumed that the data compilation shown in FIGURE 7 corresponds to the most recently obtained dataset(s) for a particular operational parameter. In this embodiment, the average trend lines 112 established for this data can be compared to the average trend lines 110 for the corresponding cleared parameter data shown in FIGURE 6. If the current parameter data differs from the cleared parameter data by a specific threshold , it can then be determined that the surfaces of the rotor blades 22 are no longer clean and therefore a significant amount of surface roughness must be present.
    [051] For example, FIGURE 8 provides a graph illustrating trendlines 110, 112 for the data sets described above with reference to FIGURES 6 and 7. As shown, trendline 112 for the current parameter data or rough deviates from trendline 110 for clean parameter data. Specifically, in the illustrated embodiment, trend lines 110, 112 exhibit significantly different slopes. In this embodiment, for example, a predetermined threshold can be established that corresponds to a specific differential slope at which the data indicates that significant surface roughness exists. Therefore, if the slope of the current trendline 112 differs from the slope of the clean trendline 110 by at least the predetermined limit, it can be determined that the surfaces of the rotor blades 22 are aerodynamically rough.
    [052] It should be appreciated that, in other embodiments, the predetermined threshold may be established using any other suitable indicator data that provide a means to distinguish clean parameter data from parameter data obtained when rotor blade surfaces are aerodynamically rough. . For example, as an alternative to using a specific differential slope, minimum and/or maximum offset values from the clean trendline 110 (e.g. one or more standard deviations) can be used as the predetermined threshold for analyzing the parameter data most recently obtained. In addition, it should be appreciated that the parameter response embedded in the parameter data may be non-linear. In this embodiment, each trend line 110, 112 may, for example, correspond to a reference line that extends tangent to a suitable fit curve associated with the parameter data.
    [053] Again with reference to FIGURE 4, at 106, a corrective action can be taken in response to the identified roughness state of the rotor blades 22. Specifically, in some embodiments, a corrective action can be taken when it is determined that the surfaces of the rotor blades 22 are aerodynamically rough. For example, as indicated above, pre-stored cleared parameter data can be compared to current parameter data to determine whether the current parameter data differs from the cleared parameter data by at least a predetermined threshold. If the current parameter data does differ from the cleared parameter data by at least the threshold, then appropriate corrective action can be taken to properly adjust the wind turbine's operation. However, if the limit is not exceeded, wind turbine operation can be continued without the need for corrective action.
    [054] In general, corrective action taken in response to the identification of aerodynamically rough rotor blades can correspond to any appropriate control action that allows the performance of rotor blades 22 and/or wind turbine 10 to be improved despite of the existence of these rough surface conditions. Specifically, it has been found that a percentage (e.g., around 0.5% to 1.5%) of the reduction in AEP caused by aerodynamically rough blades can be recovered by adapting the wind turbine to operation to accommodate the current state of roughness. of the blades 22. For example, by modifying one or more of the operating inputs of the wind turbine 10 based on the identified surface roughness, the performance losses for the rotor blade 22 (e.g. reduced climb, increased drag, earlier stop) can be reduced, to thereby result in an effective AEP gain for the wind turbine 10. Furthermore, by adapting the wind turbine to operation based on the surface condition of the rotor blades 22, the amount of noise generated by the rotor blades rotor 22 can also be reduced.
    [055] In some embodiments, the corrective action taken may correspond to adjusting the pitch angle of the rotor blades 22 in order to accommodate the surface roughness of the rotor blades 22 (particularly on the leading edge of the rotor blades 22). As indicated above, rotor blades 22 can be tilted by controlling the operation of tilt adjustment mechanisms 32.
    [056] In another embodiment, the corrective action taken may be directed at adjusting the tip velocity ratio (TSR) of the rotor blades 22 (ie, the ratio of blade tip speed to wind speed). As is generally understood, the TSR can be adjusted using any suitable control action that allows a modification of rotor speed. For example, the control action may correspond to adjusting the operation of the generator 24 (e.g., modifying the generator torque and/or generator speed), which may in turn result in the rotor speed changing. In another embodiment, the control action may correspond to rotating the nacelle 16 in order to change the angle of rotation, to thereby allow the rotor speed to be modified. In a further embodiment, the TSR can be adjusted by modifying the pitch angle of rotor blades 22 in the manner described above.
    [057] Additionally, various other corrective actions may be taken in response to the identification and/or detection of aerodynamically rough rotor blades 22. For example, in one embodiment, the controller 26 may be configured to provide an alert or other notification indicating the rough state of the rotor blades 22. This notification may be designed to signal maintenance workers that a proper maintenance operation may have to be performed. For example, upon receipt of the notification, a blade cleaning/washing operation may be scheduled to allow for the removal of any blade dirt and/or other blade deposits. In another embodiment, for example, where ice may be present on the blades of the rotor 22, the corrective action may be to carry out any suitable ice mitigation strategy (e.g., by activating heaters or any other suitable de-icing system associated with the blades). of rotor 22).
    [058] It should be appreciated that in addition to the various sensors 60, 62, 64, 66, 68, 70, 72 described above, the wind turbine 10 may also include one or more surface roughness sensors configured to directly monitor roughness. of the surface of rotor blades 22. For example, FIGURE 9 illustrates a perspective view of a rotor blade 22 having various embodiments of roughness sensors 202, 204, 206 installed thereon. As shown, rotor blade 22 includes a blade base 82 configured to mount rotor blade 22 to hub 18 of a wind turbine 10 (FIGURE 1), a blade tip 84 disposed opposite blade base 82, and body 86 which extends between the base of the blade 82 and the tip of the blade 84. The body 86 may generally define the aerodynamic shape of the rotor blade 22 and therefore may include a pressure side 88 and a suction side 90 which extends between a leading edge 92 and a trailing edge 94. Additionally, the rotor blade 22 may generally include an extension 96 that defines the total length between the base of the blade 82 and the tip of the blade 84 and a cord 98 that defines the length. between leading edge 92 and trailing edge 94. As is generally understood, cord 98 may vary in length with respect to extent 96 as body 86 extends from base of blade 82 to tip of blade 84.
    [059] Additionally, as shown in FIGURE 9, one or more harshness sensors 200, 202, 204 can be installed on and/or inside the rotor blade 22. In general, the harshness sensors 200, 202, 204 can be configured to provide surface condition data related to the surface roughness of the rotor blade 22 to the controller 26. For example, in one embodiment, the roughness sensor(s) may be a thin film anemometer 200 positioned along the outer surface of the blade 22 (e.g., at or near the leading edge 92). Thin film anemometer 200 may include, for example, a heated plate that is maintained at a constant temperature by varying the electrical current supplied to the plate. In this embodiment, the surface roughness of the rotor blade 22 can be detected by monitoring the rate of heat removal across the plate (i.e., monitoring how much current is required to keep the plate temperature constant). Typically, the rate of heat removal from the plate will be much higher with turbulent flow. Therefore, as the rate of heat removal increases, it can be assumed that the transition point from laminar flow to turbulent flow has shifted closer to the leading edge 92 of the rotor blade 22, to thereby indicate the possibility of a blade aerodynamically rough rotor 22.
    [060] In another embodiment, the roughness sensor(s) may be a thin-film photovoltaic (PV) sensor 202 positioned along the outer surface of the blade 22 (e.g., at or near the edge front 92). As is generally understood, the PV sensors 202 can be configured to convert light impinging on the sensors into an electrical current or any other suitable output. Therefore, when the PV sensor 202 is clean, the sensor 202 can be exposed to a maximum amount of light. However, when the surface of the blade 22 (and therefore the surface of the PV sensor 202) becomes rough due to dirt and/or other deposits, the exposure of the PV sensor to light will be reduced. As such, the output of the PV sensor 202 may be proportional or may otherwise be indicative of the surface roughness of the rotor blade 22. Accordingly, by analyzing the sensor output, the roughness state of the rotor blades can be estimated or determined. rotor 22.
    [061] In a further embodiment, the roughness sensor(s) may be an optical sensor 204 positioned behind a transparent panel or window 206 that forms a part of the outer surface of the blade 22. For example, optical sensor 204 may be a camera configured to capture images of window 206. In this embodiment, images captured by the camera may be analyzed to detect any change in window transparency due to dirt or other surface contamination. By monitoring and/or analyzing this change in transparency, the roughness state of the rotor blades 22 can be estimated or determined.
    [062] It should be appreciated that, in other embodiments, the roughness sensor(s) 200, 202, 204 may be any other suitable sensor(s) that allows (m) that the surface roughness of the rotor blades 22 be monitored directly. For example, in one embodiment, the roughness sensor(s) may be a pressure sensor configured to monitor pressure variations along the surface of the rotor blade 22 that occur when the transition point of the Laminar flow to transition flow moves from the sensor location towards the leading edge 94 of the blade 22, to thereby indicate that the rotor blade 22 may be aerodynamically rough.
    [063] Using the disclosed roughness sensors 200, 202, 204, the surface roughness of the rotor blades 22 can be directly estimated. Alternatively, in accordance with the method 100 described above with reference to FIGURE 4, the surface condition data provided by the roughness sensor(s) 200, 202, 204 can be used to supplement the parameter data that is analyzed by controller 26. For example, if analysis of current parameter data indicates that rotor blades 22 are aerodynamically rough, surface condition data provided by roughness sensor(s) 200, 202, 204 can be used to confirm the accuracy of this analysis. Therefore, surface condition data can be used to increase statistical confidence in the estimate made using the parameter data.
    [064] This written description uses examples to disclose the invention, including the best mode, and also to enable a person skilled in the art to practice the invention, including making and using any devices or systems and carrying out any incorporated methods. The patentable scope of the invention is defined by the claims, and may include other examples that occur to one skilled in the art. These other examples are understood to be within the scope of the claims if they include structural elements that do not differ from the literal language of the claims, or if they include equivalent structural elements with no significant differences from the literal language of the claims.
    权利要求:
    Claims (8)
    [0001]
    1. METHOD (100) FOR CONTROLLING A WIND TURBINE (10), based on an identified condition of a surface of a rotor blade (22) of the wind turbine (10), characterized by the method comprising the steps of: actively adjusting the operating input of the wind turbine (10); monitoring (102) an operating parameter of the wind turbine (10) to obtain parameter data related to the operating parameter when the operating input of the wind turbine changes through the tuning step; analyzing (104) the parameter data to identify a roughness state of the rotor blade (22) comprising comparing the parameter data to predetermined clean parameter data related to the operating parameter; and, taking (106) corrective action when it is identified that a surface of the rotor blade (22) is aerodynamically rough; wherein performing (106) a corrective action comprises adjusting at least one of a pitch angle or a tip speed ratio of the rotor blade (22) to recover from a reduction in annual energy production (AEP) caused by the state of roughness, by increasing the performance of the rotor blade (22) and/or the wind turbine (10), despite the existence of the roughness state.
    [0002]
    2. METHOD (100), according to claim 1, characterized in that the parameter data comprises combinations of operational parameter(s)/operational input(s), in which a dynamic response of the operational parameters to changes in the operational inputs is monitored to allow a significant amount of parameter data to be obtained for each combination of operational parameter(s) / operational input(s).
    [0003]
    3. METHOD (100) according to any one of claims 1 to 2, characterized in that the operational input comprises at least one of tilt angle, rotation angle, generator speed or generator torque.
    [0004]
    4. METHOD (100) according to any one of claims 1 to 3, characterized in that the operational parameter comprises at least one of shaft bending, blade bending, tower bending, power output, generator speed, generator torque , component vibration or blade noise.
    [0005]
    5. METHOD (100) according to any one of claims 1 to 4, characterized in that performing a corrective action in response to the identified roughness state comprises performing the corrective action when the parameter data differs from the predetermined clean parameter data by at least least one predetermined limit.
    [0006]
    6. METHOD according to any one of claims 1 to 5, characterized by comparing the parameter data to predetermined parameter clean data related to the operational parameter, comprising: analyzing the parameter data to establish a current trend line for the operating parameter data. parameter; analyzing the parameter predetermined clean data to establish a clean trend line for the parameter predetermined clean data; and compare the current trendline to the clean trendline.
    [0007]
    METHOD (100) according to any one of claims 1 to 6, characterized in that the method further comprises supplementing the parameter data with surface condition data obtained using a surface roughness sensor (200) in order to identify the rotor blade roughness state.
    [0008]
    8. SYSTEM FOR CONTROLLING A WIND TURBINE (10), based on an identified condition of a surface of a rotor blade (22) of the wind turbine, characterized in that the system comprises: a sensor (200) configured to monitor an operational parameter of the wind turbine when a wind turbine operating input changes; a controller (26) communicatively coupled to the sensor (200) to thereby obtain parameter data related to the operating parameter, wherein the controller (26) is configured to perform a method as defined in any one of claims 1 to 7.
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    同族专利:
    公开号 | 公开日
    US20140241878A1|2014-08-28|
    EP2772643B1|2021-10-20|
    BR102014003222A8|2016-01-12|
    EP2772643A2|2014-09-03|
    DK2772643T3|2022-01-24|
    EP2772643A3|2018-04-11|
    IN2014CH00894A|2015-05-08|
    BR102014003222A2|2015-12-08|
    US9759068B2|2017-09-12|
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    法律状态:
    2015-12-08| B03A| Publication of a patent application or of a certificate of addition of invention [chapter 3.1 patent gazette]|
    2016-01-12| B03H| Publication of an application: rectification [chapter 3.8 patent gazette]|Free format text: REFERENTE A RPI 2344 DE 08/12/2015, QUANTO AO ITEM (30). |
    2018-11-13| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2020-08-11| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2021-11-03| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2022-01-11| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 11/02/2014, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US13/779,829|2013-02-28|
    US13/779,829|US9759068B2|2013-02-28|2013-02-28|System and method for controlling a wind turbine based on identified surface conditions of the rotor blades|
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