System and method for controlling a wind turbine

Abstract

Systems and methods for controlling a wind turbine are provided. Accordingly, a controller of the wind turbine detects a loss of traction of a slip coupling based on a difference between data indicative of a rotor operating parameter and data indicative of a generator operating parameter. The controller then determines a slip angle corresponding to the loss of traction from the difference. A deterioration value for the slip coupling is determined based at least in part on the slip angle. A control action is implemented based on the deterioration value.

Description

Technical Field

[0001] This disclosure generally relates to wind turbines, and more particularly to systems and methods for controlling wind turbines based on the degradation value of sliding couplings in the drivetrain. Background Technology

[0002] Wind power is considered one of the cleanest and most environmentally friendly energy sources available today, and wind turbines are receiving increasing attention in this area. A modern wind turbine typically comprises a tower, generator, gearbox, nacelle, and one or more rotor blades. The nacelle contains the rotor assembly, which is coupled to the gearbox and then to the generator. The rotor assembly and gearbox are mounted on a base support frame located within the nacelle. One or more rotor blades use known airfoil principles to capture the kinetic energy of the wind. The rotor blades transfer this kinetic energy as rotational energy, enabling the shaft that is coupled to the gearbox or, in the absence of a gearbox, directly to the generator to rotate. The generator then converts the mechanical energy into electrical energy, which can be transmitted to a converter and / or transformer housed within the tower and subsequently deployed to the public power grid. Modern wind power generation systems typically take the form of wind farms with multiple such wind turbine generators, which are operable to supply power to a transmission system that then supplies power to the power grid.

[0003] In some cases, the rotor can be rotatably connected to the generator via a sliding coupler. The torque generated by the generator and / or the inertia of the rotor can cause a loss of traction force in the sliding coupler, resulting in slippage. Slippage of the sliding coupler can lead to its degradation. Therefore, it is desirable to implement various control actions based on the degree of degradation of the sliding coupler.

[0004] Therefore, the art is constantly seeking new and improved systems and methods to solve the aforementioned problems. Accordingly, this disclosure relates to a system and method for controlling wind turbines based on the degradation value of sliding couplings. Summary of the Invention

[0005] Aspects and advantages of the invention will be set forth in part in the description which follows, or will be obvious from the description, or may be learned by practice of the invention.

[0006] In one aspect, this disclosure relates to a method for controlling a wind turbine. The wind turbine may have a drivetrain including a rotor having one or more rotor blades mounted thereto, the rotor being rotatably coupled to a generator via a sliding coupler. The method may include using a controller to detect traction loss of the sliding coupler based on a difference between data indicating rotor operating parameters and data indicating generator operating parameters. The method may also include using the controller to determine a slip angle corresponding to the traction loss based on the difference. Additionally, a degradation value for the sliding coupler, at least partially corresponding to the slip angle, may be determined. Furthermore, the method may include implementing control actions based on the degradation value.

[0007] In one embodiment, determining the slip angle corresponding to the loss of traction based on the difference may include integrating the difference over a sampling interval via a controller to determine the slip angle corresponding to the loss of traction.

[0008] In an additional embodiment, detecting the traction loss of the sliding coupler may include receiving data indicating rotor operating parameters and data indicating generator operating parameters via a controller. The method may include filtering the data indicating rotor operating parameters and the data indicating generator operating parameters via a low-pass filter. Filtering the data may exclude at least one known parameter deviation from the determination of the difference between the data indicating rotor operating parameters and the data indicating generator operating parameters. The known parameter deviations(s) may originate from causes unrelated to the traction loss of the sliding coupler.

[0009] In another embodiment, detecting the traction loss of the sliding coupler may include determining the operating conditions of the wind turbine via a controller. Additionally, the controller may determine a slip indication threshold under the operating conditions. Furthermore, the controller may detect the absolute value of the difference between the slip indication threshold and the actual slip indication threshold.

[0010] In yet another embodiment, detecting the traction loss of the sliding coupler may include applying a delay correction to data indicating generator operating parameters via a controller. The delay correction compensates for the sampling rate difference between the data indicating rotor operating parameters and the data indicating generator operating parameters.

[0011] In one embodiment, detecting the traction loss of the sliding coupler may include determining a calibration factor for rotor operating parameters via a calibration module of the controller. The controller may apply the calibration factor to data indicating rotor operating parameters.

[0012] In an additional embodiment, the rotor operating parameters may correspond to the rotor speed. Additionally, the generator operating parameters may correspond to the generator speed.

[0013] In another embodiment, the method may include receiving the rotational speed of a portion of the high-speed shaft of the transmission system connected between a sliding coupler and a gearbox of the transmission system. The method may also include using the gear ratio of the gearbox to determine the rotor speed of the rotor based on the rotational speed of the portion of the high-speed shaft.

[0014] In yet another embodiment, the rotor operating parameters may correspond to the rotor inertia. Additionally, the generator operating parameters may correspond to the generator torque.

[0015] In an embodiment, determining the degradation value for the sliding coupler may further include determining a threshold value for each event of the slip angle. Additionally, the controller may detect a slip angle value corresponding to a loss of traction for a single event, which exceeds the threshold value for each event.

[0016] In an additional embodiment, determining the threshold value for each event magnitude for the slip angle may include determining the operating conditions of the wind turbine via a controller. Additionally, the controller may determine the threshold value for each event magnitude for the slip angle under the operating conditions.

[0017] In another embodiment, determining the operating conditions of the wind turbine may further include determining the rotor inertia via a controller. The controller may also determine the generator torque. Additionally, the controller may determine the torque difference across the sliding coupler based on the rotor inertia and the generator torque.

[0018] In yet another embodiment, determining the degradation value for the sliding connector may include adding the absolute value of the slip angle to the cumulative slip count for the sliding connector during the sampling period. The cumulative slip count may indicate the cumulative slip of the sliding connector during the sampling period.

[0019] In one embodiment, the method may include determining a life-end wear threshold for the sliding coupler based on a wear level where the likelihood of traction loss in the sliding coupler exceeds an acceptable limit. The life-end wear threshold can be represented by the cumulative slip angle. Additionally, the controller may detect the cumulative slip count approaching the life-end wear threshold.

[0020] In additional embodiments, the method may include determining the rate of increase of cumulative slippage via a controller based on cycle counts and / or time. Additionally, the method may include determining a life-end wear threshold for the sliding coupler based on a wear level where the likelihood of traction loss in the sliding coupler exceeds an acceptable limit. The life-end wear threshold can be represented by the cumulative slippage angle. Furthermore, the controller may predict the remaining service life of the sliding coupler based on the rate of increase of the cumulative slippage count and the life-end wear threshold.

[0021] In another embodiment, predicting the remaining lifespan of the sliding coupler may include associating a growth rate with the operating conditions of the wind turbine at multiple time intervals via a controller. Additionally, the method may include determining multiple predicted growth rates based at least in part on multiple predicted operating conditions. The controller may also determine, based on the multiple predicted operating conditions, the probability of approaching a life-end wear threshold at each of the multiple predicted growth rates.

[0022] In another aspect, this disclosure relates to a system for controlling a wind turbine. The system may include a rotor having one or more rotor blades mounted thereto, and the generator being rotatably coupled to the rotor via a sliding coupler. The system may also include at least one operation sensor operatively coupled to the rotor and configured to monitor rotor operating parameters during operation. Additionally, the system may include a controller communicatively coupled to the generator and the operation sensor(s). The controller may include at least one processor configured to perform a plurality of operations. The plurality of operations may include any of the operations and / or features described herein.

[0023] Technical Solution 1. A method for controlling a wind turbine, the wind turbine having a transmission system including a rotor having one or more rotor blades mounted to the rotor, the rotor being rotatably coupled to a generator via a sliding coupler, the method comprising:

[0024] The traction loss of the sliding coupler is detected by the controller based on the difference between data indicating rotor operating parameters and data indicating generator operating parameters;

[0025] The controller determines the slip angle corresponding to the loss of traction based on the difference.

[0026] Determine at least a partial degradation value for the sliding coupler corresponding to the sliding angle; and

[0027] Control actions are implemented based on the aforementioned degradation value.

[0028] Technical Solution 2. The method according to Technical Solution 1, wherein determining the slip angle corresponding to the loss of traction force based on the difference further comprises:

[0029] The difference is integrated over the sampling interval via the controller to determine the slip angle corresponding to the loss of traction.

[0030] Technical Solution 3. The method according to Technical Solution 1, wherein detecting the traction loss of the sliding coupling further includes:

[0031] The controller receives the data indicating the rotor operating parameters and the data indicating the generator operating parameters.

[0032] The data indicating the rotor operating parameters and the data indicating the generator operating parameters are filtered via a low-pass filter, wherein the filtering excludes at least one known parameter deviation due to the determination of the difference between the data indicating the rotor operating parameters and the data indicating the generator operating parameters, the at least one known parameter deviation being caused by a reason not associated with the traction loss of the sliding coupling.

[0033] Technical Solution 4. The method according to Technical Solution 3, wherein detecting the traction loss of the sliding coupling further includes:

[0034] The operating conditions of the wind turbine are determined by the controller;

[0035] The controller determines the slide indication threshold under the operating conditions; and

[0036] The controller detects the absolute value of the difference that is greater than or equal to the sliding indication threshold.

[0037] Technical Solution 5. The method according to Technical Solution 4, wherein detecting the traction loss of the sliding coupling further includes:

[0038] The controller applies a delay correction to the data indicating the generator operating parameters, wherein the delay correction compensates for the sampling rate difference between the data indicating the rotor operating parameters and the data indicating the generator operating parameters.

[0039] Technical Solution 6. The method according to Technical Solution 5, wherein detecting the traction loss of the sliding coupling further includes:

[0040] The calibration module of the controller determines the calibration factor for the rotor operating parameters; and

[0041] The calibration factor is applied to the data indicating the rotor operating parameters via the controller.

[0042] Technical Solution 7. The method according to Technical Solution 1, wherein the rotor operating parameters correspond to the rotor speed, and wherein the generator operating parameters correspond to the generator speed.

[0043] Technical Solution 8. The method according to Technical Solution 7 further includes:

[0044] The controller receives data indicating the rotational speed of a portion of the high-speed shaft of the transmission system connected between the sliding coupler and the gearbox of the transmission system; and

[0045] The rotor speed is determined by using the gear ratio of the gearbox based on the rotational speed of the portion of the high-speed shaft.

[0046] Technical Solution 9. The method according to Technical Solution 1, wherein the rotor operating parameters correspond to rotor inertia, and wherein the generator operating parameters correspond to generator torque.

[0047] Technical Solution 10. The method according to Technical Solution 1, wherein determining the degradation value for the sliding coupler further includes:

[0048] Determine a threshold value for each event quantity for the sliding angle;

[0049] The controller detects the slip angle value corresponding to the traction loss for a single event that exceeds the threshold value for each event.

[0050] Technical Solution 11. The method according to Technical Solution 10, wherein determining the threshold value of each event for the sliding angle further includes:

[0051] The operating conditions of the wind turbine are determined by the controller;

[0052] The controller determines the threshold value of each event for the sliding angle under the operating conditions.

[0053] Technical Solution 12. The method according to Technical Solution 11, wherein determining the operating conditions of the wind turbine further includes:

[0054] The rotor inertia is determined via the controller;

[0055] The generator torque is determined via the controller; and

[0056] The torque difference across the sliding coupling is determined via the controller based on the rotor inertia and the generator torque.

[0057] Technical Solution 13. The method according to Technical Solution 1, wherein determining the degradation value for the sliding connector further includes:

[0058] The absolute value of the sliding angle is added to the cumulative sliding count for the sliding connector during the sampling period, wherein the cumulative sliding count indicates the cumulative degree of sliding of the sliding connector during the sampling period.

[0059] Technical Solution 14. The method according to Technical Solution 13 further includes:

[0060] A life-end wear threshold for the sliding coupler is determined based on the wear level at which the likelihood of traction loss exceeds an acceptable limit; the life-end wear threshold is expressed as a cumulative slip angle.

[0061] The controller detects that the accumulated slip count is approaching the end-of-life wear threshold.

[0062] Technical Solution 15. The method according to Technical Solution 13 further includes:

[0063] The growth rate of the cumulative sliding count is determined by the controller based on at least one of the cycle count and time;

[0064] A life-end wear threshold for the sliding coupler is determined based on the wear level at which the possibility of traction loss in the sliding coupler exceeds an acceptable limit, and the life-end wear threshold is expressed as a cumulative slip angle.

[0065] The controller is used to predict the remaining service life of the sliding coupler based on the growth rate of the cumulative sliding count and the end-of-life wear threshold.

[0066] Technical Solution 16. The method according to Technical Solution 15, wherein predicting the remaining service life of the sliding coupler further comprises:

[0067] The controller correlates the growth rate with the operating conditions of the wind turbine at multiple time intervals.

[0068] Multiple projected growth rates are determined, at least in part, based on multiple projected operating conditions; and

[0069] The controller determines the probability of approaching the end-of-life wear threshold under each of the plurality of predicted growth rates based on the plurality of predicted operating conditions.

[0070] Technical Solution 17. A system for controlling a wind turbine, the system comprising:

[0071] A rotor having one or more rotor blades mounted thereon;

[0072] A generator, which is rotatably connected to the rotor via a sliding coupler;

[0073] At least one operating sensor operably coupled to the rotor and configured to monitor rotor operating parameters of the rotor during operation; and

[0074] A controller communicatively coupled to the generator and the at least one operating sensor, the controller including at least one processor configured to perform a plurality of operations, the plurality of operations including:

[0075] The traction loss of the sliding coupler is detected based on the difference between the data indicating rotor operating parameters and the data indicating generator operating parameters;

[0076] The difference is integrated over the sampling interval to determine the slip angle corresponding to the loss of traction force;

[0077] Determine at least a partial degradation value for the sliding coupler corresponding to the sliding angle; and

[0078] Control actions are implemented based on the aforementioned degradation value.

[0079] Technical Solution 18. The system according to Technical Solution 17, wherein determining the traction loss of the sliding coupling further includes:

[0080] Receive the data indicating the rotor operating parameters and the data indicating the generator operating parameters;

[0081] The data indicating the rotor operating parameters and the data indicating the generator operating parameters are filtered via a low-pass filter, wherein filtering the data excludes at least one known cause of parameter deviation in the determination of the difference between the data indicating the rotor operating parameters and the data indicating the generator operating parameters.

[0082] Technical Solution 19. The system according to Technical Solution 17, wherein determining the degradation value for the sliding connector further includes:

[0083] Determine the operating conditions of the wind turbine, wherein determining the operating conditions includes:

[0084] Determine the rotor inertia.

[0085] Determine the generator torque, and

[0086] The torque difference across the sliding coupling is determined based on the rotor inertia and the generator torque;

[0087] Determine the threshold value for each event quantity of the sliding angle under the operating conditions; and

[0088] Detect the slip angle value corresponding to the traction loss for a single event that exceeds the threshold value for each event.

[0089] Technical Solution 20. The system according to Technical Solution 17, wherein determining the degradation value for the sliding connector further includes:

[0090] The absolute value of the sliding angle is added to the cumulative sliding count for the sliding connector during the sampling period, wherein the cumulative sliding count indicates the cumulative degree of sliding of the sliding connector during the sampling period;

[0091] A life-end wear threshold for the sliding coupler is determined based on the wear level at which the likelihood of traction loss exceeds an acceptable limit; the life-end wear threshold is expressed as a cumulative slip angle.

[0092] The cumulative slip count is detected as it approaches the end-of-life wear threshold.

[0093] These and other features, aspects, and advantages of the invention will become more readily understood with reference to the following description and the appended claims. The accompanying drawings, which are incorporated in 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. Attached Figure Description

[0094] The invention (including its preferred mode) is fully disclosed and can be practiced by one of ordinary skill in the art in the description with reference to the accompanying drawings, in which:

[0095] Figure 1 The figure is a perspective view of one embodiment of a wind turbine according to the present disclosure;

[0096] Figure 2 The figure shows an interior perspective view of an embodiment of the nacelle of a wind turbine according to the present disclosure;

[0097] Figure 3 The figure shows a schematic diagram of one embodiment of the transmission system of a wind turbine according to the present disclosure;

[0098] Figure 4 The figure shows a block diagram of one embodiment of a controller for use with a wind turbine, according to the present disclosure;

[0099] Figure 5 The diagram shows a flowchart of an embodiment of the control logic for a system for controlling a wind turbine according to the present disclosure; and

[0100] Figure 6 The diagram illustrates the determination of degradation values ​​corresponding to sliding couplers according to this disclosure. Figure 5 A flowchart of one embodiment of the control logic portion.

[0101] The repeated use of reference characters in this specification and drawings is intended to indicate the same or similar features or elements of the invention. Detailed Implementation

[0102] Reference will now be made in detail to embodiments of the invention, one or more examples of which are illustrated in the accompanying drawings. Each example is provided by way of explanation rather than limitation of the invention. In fact, it will be apparent to those skilled in the art that various modifications and variations may be made in the invention without departing from the scope or spirit thereof. For example, a feature illustrated or described as a part of one embodiment may be used with another embodiment to produce yet another further embodiment. Therefore, it is intended that the invention cover such modifications and variations as fall within the scope of the appended claims and their equivalents.

[0103] As used in this article, the terms “first,” “second,” and “third” may be used interchangeably to distinguish one component from another and are not intended to indicate the position or importance of a single component.

[0104] Unless otherwise specified herein, the terms “connection,” “fixed,” “attached to,” etc., refer to direct connection, fixation, or attachment, as well as indirect connection, fixation, or attachment via one or more intermediate components or features.

[0105] As used herein throughout the specification and claims, approximate language is appropriate to modify any quantitative expression that may vary without altering its essential function. Therefore, values ​​modified by one or more terms such as “approximately,” “about,” and “substantially” are not limited to the specified precise value. In at least some cases, approximate language may correspond to the precision of the instrument used to measure the value, or the precision of the method or machine used to construct or manufacture the component and / or system. For example, approximate language may refer to a margin of 10 percent.

[0106] Throughout the specification and claims, the scope is defined in combination and interchangeably, and unless the context or language otherwise indicates otherwise, such scope is identified and includes all subscopes contained therein. For example, all scopes disclosed herein include endpoints, and endpoints can be combined independently of each other.

[0107] Generally, this disclosure relates to systems and methods for controlling wind turbines based at least in part on the degradation value of a sliding coupler. Typically, the rotor of a wind turbine is coupled to a generator of the wind turbine via a sliding coupler. The sliding coupler can be configured to slide if the torque across the sliding coupler (e.g., the torque difference between portions of the drive shaft connected by a support coupler) exceeds a traction force threshold for the sliding coupler. Sliding of the sliding coupler can be used to protect various components of the wind turbine from torque loads exceeding design limits. For example, generator torque can be used to slow rotor rotation. Thus, the interaction between the generator torque and the rotor's inertia can exceed the traction force of the sliding coupler, and the sliding coupler can begin to slide, as it is designed to. Sliding of the sliding coupler can be detected based on the difference between rotor operating parameters (e.g., rotor rotational speed, inertia, etc.) and generator operating parameters (e.g., generator rotor rotational speed, generator torque, etc.).

[0108] Sliding of a sliding coupler can cause wear / damage. However, since sliding couplers are designed to slide, a certain amount of sliding and corresponding wear is acceptable before repairs become necessary. Accordingly, it is desirable to determine the degradation value for the sliding coupler. The degradation value can correspond to the degree of wear / damage accumulated by the sliding coupler due to various sliding events throughout its lifespan.

[0109] One indicator of the cumulative degradation of a sliding coupler is the accumulated slip across all sliding events experienced by the coupler. In other words, the number of degrees of slip the coupler can slide during a particular sliding event can be added to the cumulative slip count for the coupler. During the continued operation of the wind turbine, the cumulative slip count can continue to accumulate until it reaches a threshold indicating an unacceptable level of wear on the coupler.

[0110] It should be recognized that the accumulation of slip counts as described herein cannot be obtained using known methods for monitoring sliding couplers. While known monitoring methods can indicate alignment offsets of the sliding coupler relative to the mounting orientation (e.g., 10°, 30°, 45°, etc.), such offsets do not indicate whether the sliding coupler has accumulated more than 360° of slip. In other words, known methods cannot indicate whether a 30° offset corresponds only to 30°, or whether the offset corresponds to 390°, 750°, etc. Furthermore, the degree of offset may not take into account slips that can occur in opposite directions. For example, based on known methods, a 40° slip in the clockwise direction followed by a 20° slip in the counterclockwise direction may result in an indication of a 20° slip / offset, while the use of the systems and methods disclosed herein may indicate a cumulative slip of 60°.

[0111] In addition to cumulative slip indicating degradation values, degradation values ​​can also be based on the degree of slip of the sliding coupler during a single slip event. Therefore, a single slip event resulting in a relatively significant degree of slip can indicate a failed or soon-to-be-failed sliding coupler. For example, a sliding coupler may be designed to slip a specified number of degrees in response to a given torque across the coupler. However, if the slip observed in response to a given torque using the systematic methods disclosed herein exceeds the expected slip, wear / damage can be indicated. By way of another example, a sliding coupler that slips a relatively significant number of degrees in response to a relatively small torque difference across the coupler can indicate an unacceptable level of wear / damage.

[0112] Now refer to the attached diagram, Figure 1 The figure shows a perspective view of one embodiment of a wind turbine 100 according to the present disclosure. As shown, the wind turbine 100 generally includes a tower 102 extending from a support surface 104, a nacelle 106 mounted on the tower 102, and a rotor 108 coupled to the nacelle 106. The rotor 108 includes a rotatable hub 110 and at least one rotor blade 112 coupled to and extending outward from the hub 110. For example, in the illustrated embodiment, the rotor 108 includes three rotor blades 112. However, in alternative embodiments, the rotor 108 may include more or fewer than three rotor blades 112. Each rotor blade 112 may be spaced apart around the hub 110 to allow the rotor 108 to rotate so that kinetic energy can be converted from wind into usable mechanical energy and subsequently into electrical energy. For example, the hub 110 may be rotatably coupled to an electrical system 150 located within the nacelle 106. Figure 2 ) generator 118 ( Figure 2 ), to allow the generation of electrical energy.

[0113] The wind turbine 100 may also include a controller 200 centralized within the nacelle 106. However, in other embodiments, the controller 200 may be located within any other component of the wind turbine 100 or at a location external to the wind turbine. Furthermore, the controller 200 may be communicatively coupled to any number of components of the wind turbine 100 to control those components. Accordingly, the controller 200 may include a computer or other suitable processing unit. Therefore, in several embodiments, the controller 200 may include suitable computer-readable instructions that, when implemented, configure the controller 200 to perform various functions, such as receiving, transmitting, and / or executing wind turbine control signals.

[0114] Now for reference Figures 2 to 3 Illustration Figure 1The diagram shows a simplified internal view of one embodiment of the nacelle 106 of the wind turbine 100 and a schematic diagram of one embodiment of the drivetrain 146. As shown, a generator 118 may be coupled to a rotor 108 to generate electrical power from the rotational energy generated by the rotor 108. For example, as shown in the illustrated embodiment, the rotor 108 may include a rotor shaft 122 coupled to a hub 110 for rotating together with the hub 110. The rotor shaft 122 may be rotatably supported by a main bearing 144. The rotor shaft 122 may then be rotatably coupled to a high-speed shaft 124 of the generator 118 via an optional gearbox 126, which is connected to a base support frame 136 via one or more torque arms 142. As generally understood, in response to rotation of the rotor blades 112 and the hub 110, the rotor shaft 122 may provide a low-speed, high-torque input to the gearbox 126. The gearbox 126 may then be configured with a plurality of gears 148 to convert a low-speed, high-torque input into a high-speed, low-torque output to drive the high-speed shaft 124 and thus the generator 118. In an embodiment, the gearbox 126 may be configured with a plurality of gear ratios to produce varying rotational speeds of the high-speed shaft for a given low-speed input, or vice versa.

[0115] In this embodiment, rotor 108 can be slowed down by torque generated by generator 118. Since generator 118 generates torque opposite to the rotation of rotor 108, high-speed shaft 124 can be equipped with a sliding coupling 154. Sliding coupling 154 prevents damage to components of transmission 146 due to overload. Accordingly, sliding coupling 154 may have a release threshold or traction force above which allows the first portion 162 and the second portion 164 of high-speed shaft 124 to rotate at different speeds. It should be appreciated that if the torsional torque at sliding coupling 154 exceeds the release / traction force threshold, generator 118 may communicatively disengage from rotor 108, and wear may accumulate on sliding coupling 154. In such a case, the torque generated by generator 118 may not be used to slow down rotor 108, or the increased rotational speed of rotor 108 may not be used for increased power output.

[0116] Each rotor blade 112 may also include a pitch control mechanism 120 configured to rotate the rotor blade 112 about its pitch axis 116. Each pitch control mechanism 120 may include a pitch drive motor 128 (e.g., any suitable electric, hydraulic, or pneumatic motor), a pitch drive gearbox 130, and a pitch drive pinion 132. In such an embodiment, the pitch drive motor 128 may be coupled to the pitch drive gearbox 130 such that the pitch drive motor 128 imparts mechanical force to the pitch drive gearbox 130. Similarly, the pitch drive gearbox 130 may be coupled to the pitch drive pinion 132 for rotation together with the pitch drive pinion 132. The pitch drive pinion 132 may then be rotatably engaged with a pitch bearing 134 connected between the hub 110 and the corresponding rotor blade 112, such that rotation of the pitch drive pinion 132 causes rotation of the pitch bearing 134. Therefore, in such an embodiment, the rotation of the pitch drive motor 128 drives the pitch drive gearbox 130 and the pitch drive pinion 132, thereby causing the pitch bearing 134 and the rotor blades(s)112 to rotate about the pitch axis 116. Similarly, the wind turbine 100 may include one or more yaw drive mechanisms 138 communicatively coupled to the controller 200, wherein each of the yaw drive mechanisms(s)138 is configured to change the angle of the nacelle 106 relative to the wind (e.g., by engaging the yaw bearing 140 of the wind turbine 100).

[0117] Special reference Figure 2 In an embodiment, the wind turbine 100 may include an environmental sensor 156 configured to collect data indicating one or more environmental conditions. The environmental sensor 156 may be operatively coupled to the controller 200. Therefore, in an embodiment, the environmental sensor(s) 156 may be, for example, a wind vane, an anemometer, lidar sensor, thermometer, barometer, or any other suitable sensor. The data collected by the environmental sensor(s) 156 may include measurements of wind speed, wind direction, wind shear, gusts, wind direction, atmospheric pressure, and / or temperature. In at least one embodiment, the environmental sensor(s) 156 may be mounted to the nacelle 106 at a leeward location of the rotor 108. In an alternative embodiment, the environmental sensor(s) 156 may be coupled to or integrated with the rotor 108. It should be appreciated that the environmental sensor(s) 156 may comprise a network of sensors and may be located remotely from the wind turbine 100.

[0118] Additionally, the wind turbine 100 may include at least one operating sensor 158. The operating sensors 158 may be configured to detect the performance of the wind turbine 100 (e.g., in response to environmental conditions). For example, the operating sensors 158 may be rotational speed sensors operatively coupled to the controller 200. The operating sensors 158 may be directed to the rotor 108 of the wind turbine 100, the rotor shaft 122 of the wind turbine 100, and / or the generator 118. The operating sensors 158 may collect data indicating the rotational speed and / or rotational position of the rotor shaft 122 and thus collect data indicating the rotational speed and / or rotational position of the rotor 108 in the form of rotor speed and / or rotor azimuth angle. In embodiments, the operating sensors 158 may be analog tachometers, DC tachometers, AC tachometers, digital tachometers, contact tachometers, non-contact tachometers, or time-frequency tachometers. In embodiments, the operating sensors 158 may be, for example, encoders, such as optical encoders. For example, the (multiple) operation sensors 158 may be configured to monitor the speed of the rotor 108 based on the passage of rotational features, such as the multiple bolts securing the hub 110 to the rotor shaft 122. In an additional embodiment, the (multiple) operation sensors 158 may be at least one accelerometer coupled to a portion of the rotor 108, such as the (multiple) rotor blades 112.

[0119] In an embodiment, (multiple) operational sensors 158 and / or (multiple) environmental sensors 156 may be configured to monitor the operational parameters of the wind turbine 100 in order to generate operational data 328. Figure 5 For example, (multiple) operational sensors 158 and / or (multiple) environmental sensors 156 can monitor at least one of wind speed, wind direction, power output of generator 118, and / or operating status of wind turbine 100.

[0120] It should also be recognized that, as used herein, the term “monitoring” and its variations indicate that various sensors of the wind turbine 100 can be configured to provide direct or indirect measurements of the monitored parameters. Therefore, the sensors described herein can, for example, be used to generate signals relating to the monitored parameters, which can then be utilized by the controller 200 to determine the conditions or response of the wind turbine 100.

[0121] Now for reference Figures 4 to 6 This presents several embodiments of a system 300 for controlling a wind turbine 100 according to the present disclosure. In particular, as shown in... Figure 4The illustrations shown are schematic diagrams of one embodiment of suitable components that may be included within system 300. For example, as shown, system 300 may include a controller 200 communicatively coupled to the operational sensors 158 and / or the environmental sensors 156. Furthermore, as shown, controller 200 includes one or more processors 206 and associated memory devices 208 configured to perform various computer-implemented functions (e.g., performing methods, steps, calculations, etc., as disclosed herein and storing related data). Additionally, controller 200 may include a communication module 210 to facilitate communication between controller 200 and various components of wind turbine 100. Furthermore, communication module 210 may include a sensor interface 212 (e.g., one or more analog-to-digital converters) to allow signals transmitted from the operational sensors 158 and / or the environmental sensors 156 to be converted into signals that can be understood and processed by processor 206. It should be appreciated that the operational sensors 158 and / or the environmental sensors 156 may be communicatively coupled to communication module 210 using any suitable means. For example, the (multiple) operational sensors 158 and / or (multiple) environmental sensors 156 may be wired to the sensor interface 212. However, in other embodiments, the (multiple) operational sensors 158 and / or (multiple) environmental sensors 156 may be wirelessly connected to the sensor interface 212, such as by using any suitable wireless communication protocol known in the art. Additionally, the communication module 210 may also be operatively coupled to the operation state control module 214, which is configured to change the operation state of at least one wind turbine.

[0122] As used herein, the term "processor" refers not only to integrated circuits known in the art as included in a computer, but also to controllers, microcontrollers, microcomputers, programmable logic controllers (PLCs), application-specific integrated circuits (ASICs), and other programmable circuits. Additionally, the memory device(s) 208 may generally include memory elements(s), including but not limited to computer-readable media (e.g., random access memory (RAM)), computer-readable non-volatile media (e.g., flash memory), floppy disks, compact disc-read-only memory (CD-ROM), magneto-optical disks (MOD), digital multifunction discs (DVDs), and / or other suitable memory elements. The memory device(s) 208 may generally be configured to store suitable computer-readable instructions, when implemented by the processor(s) 206, that configure the controller 200 to perform a variety of functions, including but not limited to detecting traction loss, determining a slip angle corresponding to traction loss, determining a degradation value for the sliding connector 154, and implementing control actions at least in part based on the degradation value, as described herein, and a variety of other suitable computer-implemented functions.

[0123] Special reference Figure 5 In one embodiment, the controller 200 may be configured to receive data indicating rotor operating parameters 302 and data indicating generator operating parameters 304. The controller 200 may then determine a difference 306 between the data indicating rotor operating parameters 302 and the data indicating generator operating parameters 304. Based on the difference 306, the controller 200 may detect a traction loss 308 in the sliding coupler 154. In one embodiment, in response to detecting the traction loss 308, the controller 200 may determine a slip angle 310 based on the difference 306. Based at least in part on the slip angle 310, a degradation value 312 for the sliding coupler 154 may be determined. Furthermore, a control action 314 may be implemented based on the determined degradation value 312.

[0124] In this embodiment, rotor operating parameter 302 may correspond to rotor speed. In other words, rotor operating parameter 302 may correspond to the rotational speed of rotor 108 of wind turbine 100. Rotor speed may be monitored by a plurality of operating sensors 158. For example, the plurality of operating sensors 158 may be an inertia measurement unit or similar sensor coupled to a portion of rotor 108. However, in this embodiment, the plurality of operating sensors 158 may be optical sensors configured to determine rotor speed based on the rate at which features such as bolts or bolts pass through the sensor field of the plurality of operating sensors 158.

[0125] In one embodiment, the rotor speed of rotor 108 can be extrapolated from data monitored by operating sensor 158. For example, controller 200 can be configured to receive data indicating a high-speed shaft rotational speed 316. The high-speed shaft rotational speed 316 can correspond to the rotational speed of a portion of high-speed shaft 124 (such as a first portion 162 of high-speed shaft 124) coupled between sliding coupler 154 and gearbox 126 of drivetrain 146. As depicted at 318, the gear ratio of gearbox 126 can be used to determine the rotor speed of rotor 108 (e.g., rotor operating parameter 302) based on the rotational speed of the portion of high-speed shaft 124. In an additional embodiment, the rotational speed of the portion of high-speed shaft 124 can be used as rotor operating parameter 302.

[0126] In an embodiment where rotor operating parameter 302 corresponds to rotor speed, generator operating parameter 304 may correspond to generator speed. In other words, generator operating parameter 304 may correspond to the rotational speed of the generator rotor of generator 118 and may be monitored by (a plurality of) operating sensors 158.

[0127] In one embodiment, rotor operating parameter 302 may correspond to rotor inertia. Rotor inertia may be directly monitored by (multiple) operating sensors 158 and / or calculated by controller 200 based on indications of the performance of wind turbine 100. In such an embodiment, generator operating parameter 304 may correspond to generator torque. Generator torque may similarly be directly monitored by (multiple) operating sensors 158 and / or determined by controller 200 based on other indications of the performance of generator 118 (e.g., power output), generator setpoint, and / or converter setpoint.

[0128] In an embodiment, detecting the traction loss 308 of the sliding coupler 154 may include filtering data indicating rotor operating parameters 302 and generator operating parameters 304 via a low-pass filter 320. In other words, filtering the data excludes at least one known parameter deviation due to the determination of the difference 306. These known parameter deviations may correspond to causes unrelated to the traction loss of the sliding coupler. For example, in an embodiment, the low-pass filter 320 may be configured to filter out certain drivetrain dynamic characteristics and / or sensor noise, which may include frequency components due to sampling and holding. In an embodiment, the low-pass filter 320 may be configured to filter out frequency components greater than or equal to three times (e.g., 3P) the rotational speed of the rotor 108.

[0129] The use of low-pass filter 320 can filter or correct for sources of known or predictable variation between rotor operating parameters 302 and generator operating parameters 304, enabling controller 200 to distinguish between signal-to-noise ratio and even small-angle events. Therefore, signal processing via low-pass filter 320 can be employed by system 300 to achieve a much higher signal-to-noise ratio and thus a much more accurate slip estimate for a given false positive rate than systems lacking the signal processing disclosed herein. Accordingly, signal processing via low-pass filter 320 facilitates the detection of slip events during the start-up and shutdown phases of wind turbine 100, which may be undetectable using conventional methods.

[0130] It should be recognized that signal processing via low-pass filter 320 can take into account known sources of variation between rotor operating parameter 302 and generator operating parameter 304. Therefore, the remaining variation between rotor operating parameter 302 and generator operating parameter 304 after signal processing can indicate slip events. It should be further recognized that, as... Figure 5 As depicted, a single low-pass filter 320 can be used to filter both rotor operating parameters 302 and generator operating parameters 304.

[0131] Data indicating rotor operating parameters 302 and data indicating generator operating parameters 304 can be generated at different sampling rates. For example, in an embodiment, rotor operating parameters 302 can be generated at a first sampling rate, while generator operating parameters can be generated at a second sampling rate. In an embodiment, the second sampling rate can be, for example, more frequent than the first sampling rate. In an embodiment, the difference in sampling rates can be due to differences in how rotor operating parameters 302 and generator operating parameters 304 are obtained. For example, in an embodiment, data indicating generator speed can have a higher fidelity than data indicating rotor speed. Additionally, in an embodiment, data indicating rotor speed may include an inherent delay. The inherent delay can be attributed to the processing / conversion of raw sensor data to rotor speed.

[0132] To compensate for the difference in sampling rates between rotor operating parameters 302 and generator operating parameters 304, in an embodiment, controller 200 may apply delay correction 322 to either rotor operating parameters 302 or generator operating parameters 304. For example, in an embodiment, controller 200 may apply delay correction 322 to data indicating generator operating parameters 304 with a second sampling rate greater than a first sampling rate indicating rotor operating parameters 302. In an embodiment, delay correction 322 may have a constant value. However, in additional embodiments, delay correction 322 may vary with either rotor operating parameters 302 or generator operating parameters 304. For example, in an embodiment, delay correction 322 may be inversely proportional to rotor speed.

[0133] It should be appreciated that, in embodiments, delay correction 322 can be used to suppress portions of data generated at the higher of the first or second sampling rate. Similarly, in embodiments, delay correction 322 can be used to extend portions of data generated at the lower of the first or second sampling rate. Suppressing or extending portions of data facilitates the determination of difference 306 based on simultaneously acquired data indicating rotor operating parameters 302 and generator operating parameters 304. Therefore, it should be further appreciated that the application of delay correction 322 ensures that difference 306 corresponds to the difference between rotor operating parameters 302 and generator operating parameters 304 at the same time, rather than an illusion of a difference in sampling rates.

[0134] In one embodiment, the controller 200 may include a calibration module 216. Therefore, in one embodiment, the calibration module may be used to determine a calibration factor 324 for the rotor operating parameter 302. As depicted at 326, the calibration factor can then be applied via the controller 200 to the data indicating the rotor operating parameter 302. The calibration factor 324 may correct for deviations between the rotor operating parameter 302 and the generator operating parameter 304. For example, the calibration factor 324 may correspond to uncertainties in the gearbox ratio.

[0135] In embodiments, deviations can be generated by methods for collecting data indicating rotor operating parameters 302, and thus can correspond to the difference between actual operating parameters and monitored operating parameters. For example, in an embodiment where rotor operating parameters 302 correspond to rotor speed, the measured rotor speed may deviate from the actual rotor speed (as may be determined by other monitoring means). In such embodiments, a calibration factor 324 can be used to align the measured rotor speed with the actual rotor speed. Therefore, the calibration factor can be determined based on historical monitoring of the wind turbine 100. For example, in an embodiment where the operating sensors(s)158 are optical sensors, differences or inconsistencies in the spacing of the bolt patterns connecting rotor 108 to rotor shaft 122 can cause deviations in the apparent rotational speed of rotor 108.

[0136] In one embodiment, the calibration factor 324 can be derived from the exponential moving average of parameters derived from rotor operating parameters 302 and generator operating parameters 304. In such an embodiment, the use of the exponential moving average reduces the data complexity surrounding the calibration factor 324 and thus improves the efficiency of system 300.

[0137] To determine whether the difference 306 indicates slippage of the sliding connector 154, in an embodiment, the controller 200 may be configured to receive operational data 328 from an environmental sensor 156 and / or an operation sensor 158. Based on the received operational data 328, the controller 200 may determine the operating condition 330 of the wind turbine 100. Then, in an embodiment, the controller 200 may determine a slippage indication threshold 332 under operating condition 330. The slippage indication threshold 332 may therefore vary depending on operating condition 330. As depicted at 334, the controller 200 may determine whether the difference 306 is greater than the slippage indication threshold 332. As depicted at 336, in embodiments where the difference 306 is not greater than the slippage indication threshold 332, the method disclosed herein may cease, where the difference 306 may be attributed to a cause other than slippage of the sliding connector 154. However, in embodiments where the difference 306 is greater than or equal to the slippage indication threshold 332, slippage may be indicated, and a slippage angle 310 may be determined. It should be recognized that the use of the slip indication threshold 332 can be used to isolate known causes of differences between rotor operating parameters 302 and generator operating parameters 304 that are not attributable to slip during certain operating conditions 330 of the wind turbine. This isolation can cause the corresponding difference 306 to be excluded from the determination of the degradation value 312 for the slip coupling 154.

[0138] As depicted at 338, in an embodiment, controller 200 may be configured to integrate the difference 306 within sampling interval 340, since the degree by which the sliding coupler 154 has slid can be the integral of the difference between rotor operating parameters 302 and generator operating parameters 304. Therefore, by integrating the difference 306 within sampling interval 318, controller 200 can determine the slip angle 310 corresponding to traction loss 308. By way of example, in an embodiment where rotor operating parameters 302 and generator operating parameters 304 correspond to rotational speed, the rotational speed can be measured in degrees per second. Therefore, integrating the absolute value of the difference 306 within sampling interval 340 outputs the slip angle 310 during sampling interval 340. In other words, controller 200 can convert the difference 306 between rotor speed, rotor speed, and generator speed into the degree (as an absolute value) by integration of the sliding coupler 154 during a specific slip event.

[0139] Still referencing Figure 5 And also refer to Figure 6 In an embodiment, determining the degradation value 312 may include determining a threshold value 342 for each event of the slip angle 310. The threshold value 342 for each event may correspond to the maximum degree the slip connector 154 can slide during a single slip event without directly making the implementation of control action 314 necessary. Therefore, in an embodiment, the controller 200 may detect a slip angle value 344 corresponding to a loss of traction for a single event that exceeds the threshold value 342 for each event.

[0140] In an embodiment, the threshold value 342 for each event may vary depending on the operating conditions 330 of the wind turbine 100. In other words, the maximum degree that the sliding coupling 154 can slide during a single sliding event may be greater during some operating conditions 330 than during others. For example, the threshold value 342 for each event may be larger during emergency braking and / or extreme turbulence events of the rotor 108. In contrast, the threshold value 342 for each event may be relatively lower during standard operation, such as during nominal turbine operation, start-up operation, and / or idling / parking operation. Therefore, in an embodiment, the controller 200 may determine the operating conditions 330 of the wind turbine 100. As depicted at 346, the controller may then determine / specify the threshold value 342 for each event for the slip angle 310 under operating conditions 330.

[0141] To determine the operating conditions 330 that form the basis for each event magnitude threshold 342, in an embodiment, the controller 200 may determine the rotor inertia 348 and the generator torque 350. The controller 200 may then determine the torque difference 352 across the sliding coupler 154 based on the rotor inertia 348 and the generator torque 350. Accordingly, each event magnitude threshold 342 may correspond to the maximum degree to which the sliding coupler 154 can slide in response to a specific torque difference 352 across the sliding coupler 154. For example, in an embodiment, a relatively significant degree of sliding of the sliding coupler 154 in response to a relatively insignificant torque difference 352 may indicate wear / damage to the sliding coupler 154.

[0142] like Figure 5 and Figure 6 In embodiments depicted where the slip angle value 344 does not exceed a per-event value threshold 342 or where the per-event value threshold 342 is not adopted by system 300, determining the degradation value 312 may include adding the absolute value of the slip angle 310 to the cumulative slip count 354 within the sampling period 356. The sampling period 356 may, for example, correspond to the period elapsed since the installation of the sliding coupler 154 and / or maintenance activities performed on the transmission system 146. Accordingly, the cumulative slip count 354 may indicate the cumulative slip of the sliding coupler 154 within the sampling period 356. It should be appreciated that the accumulation of slip of the sliding coupler 154 may correspond to wear / deterioration of the sliding coupler 154.

[0143] It should be further appreciated that, in this embodiment, the slip angle 310 may be converted by the controller 200 into a damage factor. The damage factor may indicate the degree of damage / wear caused by the sliding coupler 154 during a slip event. Therefore, in such an embodiment, determining the degradation value 312 may include adding the damage factor to the cumulative damage value over the sampling period 356.

[0144] In an embodiment, an increase in the cumulative slip count 354 can indicate a reduction in the remaining service life of the sliding coupler 154. In other words, as the sliding coupler 154 accumulates slippage, it can accumulate wear and approach a point where maintenance / replacement may be necessary. Therefore, in an embodiment, a life-end wear threshold 358 can be determined for the sliding coupler 154. The life-end wear threshold 358 can correspond to a wear level where the likelihood of traction loss in the sliding coupler 154 exceeds an acceptable limit.

[0145] In an embodiment, the end-of-life wear threshold 358 may be established based on an engineering dataset and therefore an engineering diagnostic expert system. The engineering diagnostic expert system may include representations of engineering domain knowledge, such as troubleshooting guidelines, anomaly verification reports, post-incident reports, design specifications, test reports, and / or other captures of human expert experience and decision-making knowledge.

[0146] As depicted at 360°, controller 200 can detect the cumulative slip count 354 approaching the end-of-life wear threshold 358. In embodiments where the cumulative slip count 354 crosses or exceeds the end-of-life wear threshold 358, control action 314 can be implemented. It should be appreciated that the end-of-life wear threshold 358 can be expressed in degrees or radians as a cumulative slip angle.

[0147] In embodiments where the cumulative slip count 354 does not meet or exceeds the end-of-life wear threshold 358, the controller 200 may continue to add the absolute value of the slip angle 310 to the cumulative slip count 354.

[0148] In one embodiment, controller 200 may determine the growth rate 362 of the cumulative slip count 354 based on cycle counts and / or time. Controller 200 may then be configured to predict the remaining service life 364 of the slip coupler 154 based on the growth rate 362 of the cumulative slip count 354 and a life-end wear threshold 358. For example, controller 200 may determine the growth rate 362 based on cycle counts. Based on this determination, controller 200 may predict the number of remaining operating cycles / hours / days / etc. before the cumulative slip count 354 is expected to be met or exceed the life-end wear threshold 358. This prediction may, for example, facilitate the scheduling of maintenance activities and / or inform decision cycles regarding the utilization rate of the wind turbine 100.

[0149] As depicted at 366, predicting remaining useful life 364 may include associating the growth rate 362 with at least one operating condition 330 of the wind turbine 100 at multiple time intervals 368. The correlation may indicate that the growth rate 362 is greater during some time intervals 368 than during other time intervals 368. For example, the correlation may indicate that the growth rate 362 is greater in a particular location during winter months than during summer months. By another example, the correlation may indicate that the growth rate 362 is greater during daytime hours than during dark hours. Furthermore, the correlation may indicate that the growth rate 362 is greater during transitions between operating states of the wind turbine 100 (e.g., transitions from operating state to idling state and from idling state to operating state).

[0150] In an embodiment, controller 200 may utilize the correlation between growth rate 362 and operating conditions(s) 330 to determine a plurality of predicted growth rates 370. The plurality of predicted growth rates 370 may be based at least in part on a plurality of predicted operating conditions. The plurality of predicted operating conditions may be indicated by at least one predicted dataset 372. Controller 200 may then determine, based on the plurality of predicted operating conditions, the probability 374 of approaching the end-of-life wear threshold 358 under each of the plurality of predicted growth rates 370. It should be appreciated that each of the probabilities 374 may form a confidence interval indicating the percentage likelihood of reaching the end-of-life wear threshold 358 under the specific predicted operating conditions. This confidence interval may, for example, facilitate the scheduling of maintenance activities and / or inform the decision-making cycle regarding the utilization rate of the wind turbine 100.

[0151] In an embodiment, system 300 may implement control action 314 based on a degradation value 312 for the sliding coupler 154. For example, in an embodiment, control action 314 may include generating an alarm. The generation of an alarm facilitates the scheduling of maintenance events to address indicated wear / damage to the sliding coupler 154. Therefore, an alarm may include audible signals, visual signals, warnings, notifications, system inputs, and / or any other system that can identify the root cause to the operator. It should be appreciated that control action 314 as described herein may further include any suitable commands or constraints on controller 200. For example, in an embodiment, control action 314 may include temporarily derating the wind turbine 100. Additionally, in an embodiment, control action 314 may include restricting the operation of at least one component of the wind turbine 100. For example, control action 314 may restrict pitch of the rotor blades 112 of the wind turbine 100 and / or yaw of the nacelle 106.

[0152] Furthermore, those skilled in the art will recognize the interchangeability of various features from different embodiments. Similarly, those skilled in the art can mix and match the various method steps and features described, as well as other known equivalents for each such method and feature, to construct additional systems and techniques based on the principles of this disclosure. It will be understood, of course, that not all such objectives or advantages described above can necessarily be achieved according to any particular embodiment. Therefore, for example, those skilled in the art will recognize that the systems and techniques described herein may be embodied or performed in a manner that achieves or optimizes one or a set of advantages as taught herein, without necessarily achieving other objectives or advantages as may be taught or suggested herein.

[0153] This written description uses examples to disclose the invention (including the best mode) and also enables any person skilled in the art to practice the invention (including making and using any device or system, and performing any incorporated methods). The patentability of the invention is defined by the claims and may include other examples that would occur to those skilled in the art. Such other examples are intended to be within the scope of the claims if they include structural elements that are not different from the literal language of the claims, or if they include equivalent structural elements that are not substantially different from the literal language of the claims.

[0154] Further aspects of the invention are provided by the subject matter of the following provisions:

[0155] Clause 1. A method for controlling a wind turbine, the wind turbine having a drive system including a rotor having one or more rotor blades mounted to the rotor, the rotor being rotatably coupled to a generator via a sliding coupler, the method comprising: detecting a traction loss of the sliding coupler based on a difference between data indicating rotor operating parameters and data indicating generator operating parameters via a controller; determining a slip angle corresponding to the traction loss based on the difference via the controller; determining a degradation value for the sliding coupler that at least partially corresponds to the slip angle; and performing a control action based on the degradation value.

[0156] Clause 2. The method according to Clause 1, wherein determining the slip angle corresponding to the loss of traction based on the difference further comprises: integrating the difference over a sampling interval via a controller to determine the slip angle corresponding to the loss of traction.

[0157] Clause 3. The method according to any of the foregoing clauses, wherein detecting the traction loss of the sliding coupler further comprises: receiving data indicating rotor operating parameters and data indicating generator operating parameters via a controller; filtering the data indicating rotor operating parameters and the data indicating generator operating parameters via a low-pass filter, wherein the filtering excludes at least one known parameter deviation due to the determination of the difference between the data indicating rotor operating parameters and the data indicating generator operating parameters, the at least one known parameter deviation being caused by a cause not associated with the traction loss of the sliding coupler.

[0158] Clause 4. The method according to any of the foregoing clauses, wherein detecting the traction loss of the slip coupling further comprises: determining the operating conditions of the wind turbine via a controller; determining a slip indication threshold under the operating conditions via a controller; and detecting, via a controller, the absolute value of the difference that is greater than or equal to the slip indication threshold.

[0159] Clause 5. The method according to any of the foregoing clauses, wherein detecting the traction loss of the sliding coupler further comprises: applying a delay correction via a controller to data indicating generator operating parameters, wherein the delay correction compensates for the sampling rate difference between the data indicating rotor operating parameters and the data indicating generator operating parameters.

[0160] Clause 6. The method according to any of the foregoing clauses, wherein detecting the traction loss of the sliding coupler further comprises: determining a calibration factor for the rotor operating parameters via a calibration module of the controller; and applying the calibration factor to data indicating the rotor operating parameters via the controller.

[0161] Clause 7. The method according to any of the foregoing clauses, wherein the rotor operating parameters correspond to the rotor speed, and wherein the generator operating parameters correspond to the generator speed.

[0162] Clause 8. The method according to any of the foregoing clauses further includes: receiving data via a controller indicating the rotational speed of a portion of the high-speed shaft of the transmission system connected between the sliding coupler and the gearbox of the transmission system; and determining the rotor speed of the rotor based on the rotational speed of the portion of the high-speed shaft using the gear ratio of the gearbox.

[0163] Clause 9. The method according to any of the foregoing clauses, wherein the rotor operating parameters correspond to the rotor inertia, and wherein the generator operating parameters correspond to the generator torque.

[0164] Clause 10. The method according to any of the foregoing clauses, wherein determining the degradation value for the sliding coupler further comprises: determining a threshold value for each event of the slip angle; and detecting, via a controller, a slip angle value corresponding to a loss of traction for a single event that exceeds the threshold value for each event.

[0165] Clause 11. The method according to any of the foregoing clauses, wherein determining the threshold value for each event with respect to the slip angle further comprises: determining the operating conditions of the wind turbine via a controller; and determining the threshold value for each event with respect to the slip angle under the operating conditions via a controller.

[0166] Clause 12. The method according to any of the foregoing clauses, wherein determining the operating conditions of the wind turbine further comprises: determining the rotor inertia via a controller; determining the generator torque via a controller; and determining the torque difference across the sliding coupling based on the rotor inertia and the generator torque via a controller.

[0167] Clause 13. The method according to any of the foregoing clauses, wherein determining the degradation value for the sliding connector further comprises: adding the absolute value of the sliding angle to the cumulative sliding count for the sliding connector during the sampling period, wherein the cumulative sliding count indicates the accumulation of the sliding degree of the sliding connector during the sampling period.

[0168] Clause 14. The method according to any of the foregoing clauses further includes: determining a life-end wear threshold for the sliding coupler based on a wear level where the likelihood of traction loss in the sliding coupler exceeds an acceptable limit, the life-end wear threshold being expressed in terms of cumulative slip angles; and detecting, via a controller, the approach of the cumulative slip count to the life-end wear threshold.

[0169] Clause 15. The method according to any of the foregoing clauses further includes: determining, via a controller, the growth rate of the cumulative slip count based on at least one of cycle count and time; determining a life-end wear threshold for the slip coupler based on a wear level where the likelihood of traction loss in the slip coupler exceeds an acceptable limit, the life-end wear threshold being expressed in terms of cumulative slip angle; and using the controller to predict the remaining service life of the slip coupler based on the growth rate of the cumulative slip count and the life-end wear threshold.

[0170] Clause 16. The method according to any of the foregoing clauses, wherein predicting the remaining service life of the sliding coupler further comprises: associating the growth rate with the operating conditions of the wind turbine via a controller at multiple time intervals; determining multiple predicted growth rates based at least in part on the multiple predicted operating conditions; and determining, via the controller, the probability of approaching the end-of-life wear threshold at each of the multiple predicted growth rates based on the multiple predicted operating conditions.

[0171] Clause 17. A system for controlling a wind turbine, the system comprising: a rotor having one or more rotor blades mounted thereto; a generator rotatably coupled to the rotor via a sliding coupler; at least one operating sensor operably coupled to the rotor and configured to monitor rotor operating parameters of the rotor in operation; and a controller communicatively coupled to the generator and the at least one operating sensor, the controller including at least one processor configured to perform a plurality of operations, the plurality of operations including: detecting traction loss of the sliding coupler based on a difference between data indicating rotor operating parameters and data indicating generator operating parameters; integrating the difference over a sampling interval to determine a slip angle corresponding to the traction loss; determining a degradation value for the sliding coupler that at least partially corresponds to the slip angle; and implementing control actions based on the degradation value.

[0172] Clause 18. A system according to any of the foregoing clauses, wherein determining the traction loss of the sliding coupler further comprises: receiving data indicating rotor operating parameters and data indicating generator operating parameters; filtering the data indicating rotor operating parameters and the data indicating generator operating parameters via a low-pass filter, wherein filtering the data excludes at least one known cause of parameter deviation in the determination of the difference between the data indicating rotor operating parameters and the data indicating generator operating parameters.

[0173] Clause 19. A system pursuant to any of the foregoing clauses, wherein determining the degradation value for the sliding coupler further comprises: determining the operating conditions of the wind turbine, wherein determining the operating conditions comprises: determining the rotor inertia, determining the generator torque, and determining the torque difference across the sliding coupler based on the rotor inertia and the generator torque; determining a threshold value for each event of the slip angle under the operating conditions; and detecting a slip angle value exceeding the threshold value for each event corresponding to a loss of traction for a single event.

[0174] Clause 20. A system pursuant to any of the foregoing clauses, wherein determining the degradation value for a sliding coupler further comprises: adding the absolute value of the slip angle to the cumulative slip count for the sliding coupler during the sampling period, wherein the cumulative slip count indicates the accumulation of slip of the sliding coupler during the sampling period; determining a life-end wear threshold for the sliding coupler based on a wear level where the likelihood of traction loss of the sliding coupler exceeds an acceptable limit, the life-end wear threshold being represented by the cumulative slip angle; and detecting the approach of the cumulative slip count to the life-end wear threshold.

Claims

1. A method for controlling a wind turbine, the wind turbine having a drive system including a rotor having one or more rotor blades mounted to the rotor, the rotor being rotatably coupled to a generator via a sliding coupler, the method comprising: The traction loss of the sliding coupler is detected by the controller based on the difference between data indicating rotor operating parameters and data indicating generator operating parameters; The controller determines the slip angle corresponding to the loss of traction based on the difference. Determine at least a partial degradation value for the sliding connector corresponding to the sliding angle; and Control actions are implemented based on the aforementioned degradation value. The detection of the traction loss of the sliding coupling further includes: The controller receives data indicating the rotor operating parameters and data indicating the generator operating parameters. The data indicating the rotor operating parameters and the data indicating the generator operating parameters are filtered via a low-pass filter, wherein the filtering excludes at least one known parameter deviation from the determination of the difference between the data indicating the rotor operating parameters and the data indicating the generator operating parameters, the at least one known parameter deviation being caused by a reason not associated with the traction loss of the sliding coupling.

2. The method according to claim 1, wherein, Determining the slip angle corresponding to the loss of traction force based on the difference further includes: The difference is integrated over the sampling interval via the controller to determine the slip angle corresponding to the loss of traction.

3. The method according to claim 1, wherein, Detecting the traction loss of the sliding coupling further includes: The operating conditions of the wind turbine are determined by the controller; The controller determines the slide indication threshold under the operating conditions; and The controller detects the absolute value of the difference that is greater than or equal to the sliding indication threshold.

4. The method according to claim 3, wherein, Detecting the traction loss of the sliding coupling further includes: The controller applies delay correction to the data indicating the generator operating parameters, wherein the delay correction compensates for the sampling rate difference between the data indicating the rotor operating parameters and the data indicating the generator operating parameters.

5. The method according to claim 4, wherein, Detecting the traction loss of the sliding coupling further includes: The calibration module of the controller determines the calibration factor for the rotor operating parameters; and The calibration factor is applied to the data indicating the rotor operating parameters via the controller.

6. The method according to claim 1, wherein, The rotor operating parameters correspond to the rotor speed, and the generator operating parameters correspond to the generator speed.

7. The method of claim 6, further comprising: The controller receives data indicating the rotational speed of a portion of the high-speed shaft of the transmission system connected between the sliding coupler and the gearbox of the transmission system; and The rotor speed is determined by using the gear ratio of the gearbox based on the rotational speed of the portion of the high-speed shaft.

8. The method according to claim 1, wherein, The rotor operating parameters correspond to the rotor inertia, and the generator operating parameters correspond to the generator torque.

9. The method according to claim 1, wherein, Determining the degradation value for the sliding connector further includes: Determine a threshold value for each event quantity for the sliding angle; The controller detects the slip angle value corresponding to the traction loss for a single event that exceeds the threshold value for each event.

10. The method according to claim 9, wherein, Determining the threshold value for each event quantity for the sliding angle further includes: The operating conditions of the wind turbine are determined by the controller; The controller determines the threshold value of each event for the sliding angle under the operating conditions.

11. The method according to claim 10, wherein, Determining the operating conditions of the wind turbine further includes: The rotor inertia is determined via the controller; The generator torque is determined via the controller; and The torque difference across the sliding coupling is determined via the controller based on the rotor inertia and the generator torque.

12. The method according to claim 1, wherein, Determining the degradation value for the sliding connector further includes: The absolute value of the sliding angle is added to the cumulative sliding count for the sliding connector during the sampling period, wherein the cumulative sliding count indicates the cumulative degree of sliding of the sliding connector during the sampling period.

13. The method of claim 12, further comprising: A life-end wear threshold for the sliding coupler is determined based on the wear level at which the possibility of traction loss in the sliding coupler exceeds an acceptable limit, and the life-end wear threshold is expressed based on the cumulative slip angle. and The controller detects that the accumulated slip count is approaching the end-of-life wear threshold.

14. The method of claim 12, further comprising: The growth rate of the cumulative sliding count is determined by the controller based on at least one of the cycle count and time; A life-end wear threshold for the sliding coupler is determined based on the wear level at which the possibility of traction loss in the sliding coupler exceeds an acceptable limit, and the life-end wear threshold is expressed based on the cumulative slip angle. The controller is used to predict the remaining service life of the sliding coupler based on the growth rate of the cumulative sliding count and the end-of-life wear threshold.

15. The method according to claim 14, wherein, Predicting the remaining service life of the sliding coupler further includes: The controller correlates the growth rate with the operating conditions of the wind turbine at multiple time intervals. Multiple projected growth rates are determined, at least in part, based on multiple projected operating conditions; and The controller determines the probability of approaching the end-of-life wear threshold under each of the plurality of predicted growth rates based on the plurality of predicted operating conditions.

16. A system for controlling a wind turbine, the system comprising: A rotor having one or more rotor blades mounted thereon; A generator, which is rotatably connected to the rotor via a sliding coupler; At least one operating sensor is operatively coupled to the rotor and configured to monitor rotor operating parameters of the rotor during operation; and A controller communicatively coupled to the generator and the at least one operating sensor, the controller including at least one processor configured to perform a plurality of operations, the plurality of operations including: The traction loss of the sliding coupler is detected based on the difference between the data indicating rotor operating parameters and the data indicating generator operating parameters; The difference is integrated over the sampling interval to determine the slip angle corresponding to the loss of traction force; Determine at least a partial degradation value for the sliding coupler corresponding to the sliding angle; and Control actions are implemented based on the aforementioned degradation value. The determination of the traction loss of the sliding coupling further includes: Receive data indicating the rotor operating parameters and data indicating the generator operating parameters; The data indicating the rotor operating parameters and the data indicating the generator operating parameters are filtered via a low-pass filter, wherein filtering the data excludes at least one known cause of parameter deviation in the determination of the difference between the data indicating the rotor operating parameters and the data indicating the generator operating parameters.

17. The system according to claim 16, wherein, Determining the degradation value for the sliding connector further includes: Determine the operating conditions of the wind turbine, wherein determining the operating conditions includes: Determine the rotor inertia. Determine the generator torque, and The torque difference across the sliding coupling is determined based on the rotor inertia and the generator torque; Determine the threshold value for each event quantity of the sliding angle under the operating conditions; and Detect the slip angle value corresponding to the traction loss for a single event that exceeds the threshold value for each event.

18. The system according to claim 16, wherein, Determining the degradation value for the sliding connector further includes: The absolute value of the sliding angle is added to the cumulative sliding count for the sliding connector during the sampling period, wherein the cumulative sliding count indicates the cumulative degree of sliding of the sliding connector during the sampling period; A life-end wear threshold for the sliding coupler is determined based on the wear level at which the likelihood of traction loss exceeds an acceptable limit, the life-end wear threshold being represented by the cumulative slip angle; and The cumulative slip count is detected as it approaches the end-of-life wear threshold.

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