Method and device for monitoring state of wind turbine by means of vibration analysis

Abstract

The invention relates to a method for monitoring the state of a wind turbine (1) by evaluating vibrations of at least one rotor blade (6) of a rotor (4) of the wind turbine (1). The method comprises the following steps: detecting vibrations of the at least one rotor blade (6) by means of at least one vibration sensor arranged in or on the rotor blade (6); detecting at least one acceleration value and / or rotation rate value at at least one position of an acceleration sensor (11, 21) and / or a gyroscope sensor (12, 22) arranged in or on the rotor blade (6); determining an operating state of the rotor (4) and / or the rotor blades (6) as a function of the at least one acceleration value and / or rotation rate value; and analyzing the vibrations of the at least one rotor blade (6) taking into account the operating state of the rotor (4) and / or of the rotor blade (6). The invention further relates to a device for monitoring the state of a wind turbine (1), comprising at least one vibration sensor arranged in or on at least one rotor blade (6) of the wind turbine (1) for detecting vibrations of the at least one rotor blade (6). The device is characterized in that acceleration sensors (11, 21) and / or gyroscopic sensors (12, 22) are arranged in or on the rotor blade (6), and in that an evaluation device is provided for carrying out such a method for evaluating the detected vibrations.

Description

Technical Field

[0001] This invention relates to a method for monitoring the condition of a wind power plant by analyzing vibrations detected in or on at least one rotor blade. Furthermore, the invention relates to an apparatus having at least one vibration sensor disposed in or on the rotor blade. Background Technology

[0002] The vibration of rotor blades during wind power equipment operation can provide information about the condition of the blades themselves and, if necessary, about connected components, such as the powertrain of the wind power equipment, as described, for example, in document WO2006 / 012827A1. By analyzing the measured vibrations, also known as oscillations, for example in terms of amplitude and / or frequency of occurrence, aging assessments and / or damage identification of the rotor blades can be performed. Furthermore, bearing damage in the powertrain can also be identified within the rotor blades. Additionally, it is possible to directly identify the occurrence of damage events, such as blade impacts or lightning strikes, through vibration detection. Increased icing on the rotor blades can also be detected.

[0003] In vibration analysis, the measured vibration spectrum is typically compared to a reference spectrum. It has been demonstrated that when information about the operating state of the turbine, rotor, and especially the blades is available and considered, determined deviations can be more reliably assigned to typical fault profiles and causes. Typically, operating state data is provided as process data by the turbine controller. However, this data usually does not involve the blades; it is often only time-averaged effective values ​​and also has latency. The turbine controller's process data therefore provides only indirect information about the state of the rotor and rotor blades. This type of process data is sufficient for monitoring steady-state operation. However, in practice, assessment of instantaneous states is also required to ensure continuous monitoring.

[0004] Furthermore, apparatus and methods for monitoring the condition of rotor blades in wind power equipment are known. These apparatuses and methods utilize strain measurement sensors and / or acceleration sensors in the rotor blades to determine the bending of the rotor blades under load conditions, for example, according to documents WO2013 / 097860A1 or EP3191791B1. Information can be extracted from the load conditions for controlling the wind power equipment, for example, for setting collective or individual pitch angles (i.e., the rotation angle of the blades about their longitudinal axis) or for orienting the rotor in the wind via tower rotation. Summary of the Invention

[0005] The objective of this invention is to provide improved condition monitoring by analyzing the vibration of at least one rotor blade, which allows for condition detection, particularly damage detection and event detection, with increased accuracy, thereby expanding the feasibility of monitoring wind power equipment.

[0006] This task is accomplished by a method or apparatus having the features of the corresponding independent claim. Advantageous designs and extensions are the subject of the dependent claims.

[0007] The method according to the present invention for monitoring the state of a wind power equipment by analyzing vibrations detected in or on at least one rotor blade has the following steps: detecting vibrations of the at least one rotor blade using at least one vibration sensor arranged in or on the rotor blade; detecting at least one acceleration value and / or rotational rate value at at least one location of an accelerometer sensor and / or a gyroscope sensor arranged in or on the rotor blade; determining the operating state of the rotor and / or rotor blade based on the at least one acceleration value and / or rotational rate value; and finally, analyzing the vibrations of the at least one rotor blade taking into account the operating state of the rotor and / or rotor blade.

[0008] Since the operating state of the rotor and / or rotor blades is determined directly in or on the rotor blades themselves using accelerometers and / or gyroscopes, information about the current and actual operating state is directly available and can be considered individually for the rotor blade and correctly correlated in time when assessing the vibration of the rotor blade.

[0009] Here, in one embodiment of the method, the operating state relates to the rotational position of the rotor and therefore to the basic orientation of the rotor blades, such as whether the blades are vertically upward or downward, or horizontally to the right or left. The rotational position of the rotor can be determined by acceleration values ​​measured by acceleration sensors in or on the rotor blades, based on the gravitational component of the acceleration value that varies sinusoidally with rotor rotation.

[0010] The vibration spectrum may differ slightly from each other for different blade orientations. To identify damage or icing of the rotor blades, a comparison with a reference spectrum can be made, for example. Small deviations from the reference spectrum can be identified with particular sensitivity if the reference spectrum was recorded under the same blade orientation or if the reference spectrum is available for different blade orientations.

[0011] In another embodiment of the method, the operating states relate to the axial rotational position and / or axial torsion and / or bending of the rotor blades. These operating states of the rotor blades also affect their (inherent) vibrations and thus the vibration spectrum. Small deviations from the reference spectrum can be identified with particular sensitivity when the reference spectrum is recorded under the same or at least similar operating states of the blades.

[0012] The axial rotational position of the rotor blades (also known as the pitch angle) can be measured directly on or in the blades, for example, using a gyroscope sensor, also known as a rotational rate sensor. Therefore, according to the present invention, information exists regarding the current pitch angle of the relevant rotor blades, not merely information about the potentially time-shifted nominal pitch angle value to be set, which can be retrieved from the upper-level control system (turbine controller) according to existing technology. Since the vibration characteristics are substantially different during pitch angle adjustment compared to static operation (clamping force changes during movement, and the blades themselves twist), this information is necessary for the correct allocation and evaluation of the vibration spectrum. Misinterpretation of the vibration spectrum and potential false alarms can be avoided. Furthermore, the location of pitch angle errors can be directly measured in this way and, if necessary, signaled as a signal.

[0013] A particular advantage of using a gyroscope sensor is that a time-interval sampling current for the rotor's rotation angle can be simultaneously derived from time-interval sampling currents of measurements from other sensors (such as accelerometers). Therefore, it is possible to identify and measure kinematic vibrations synchronized with the rotational speed, such as the gear meshing frequency from the transmission stage, at any time, even when the rotor does not have a precisely constant rotational speed. In addition to monitoring the powertrain itself, it is thus possible to eliminate signal components caused by the kinematics of the powertrain as much as possible from the signal, allowing for the analysis of blade-related frequencies without interference.

[0014] Furthermore, the operating state may involve bending or bending moment at the root of the rotor blades. The bending or bending moment describes the load state of the rotor blades.

[0015] The load on the rotor blades varies dynamically according to wind conditions and is further varied by subsequent actions of the turbine controller, which attempts to generate optimized electrical power by adjusting the rotor's orientation in the wind and the blade pitch angle. Due to this dynamic nature, the measured vibration spectrum undergoes continuous variation. Individual states (which may also be reflected differently in individual blades) cannot be clearly distinguished by time-delayed and averaged information about the operating state to compensate for their impact on the spectrum through time-discrete calculations.

[0016] According to the present invention, vibration analysis can be improved by using current information on the load of the rotor blades, measured on the blades in question. The vibration spectrum of each blade can be correlated with the instantaneous load state of each blade. In contrast, without such current load information, only correlation with the overall operating state of the turbine can be achieved.

[0017] In a preferred embodiment of this method, information from the at least one vibration sensor and, on the other hand, information from the at least one accelerometer sensor and / or the at least one gyroscope sensor are detected and evaluated synchronously with each other in time. This time-synchronized and therefore phase-stable data detection of all measurement parameters enables the accurate consideration of different operating states when evaluating the vibration spectrum. Preferably, the measurements from the vibration sensor and the at least one accelerometer sensor and / or the at least one gyroscope sensor have a time resolution and time correlation relative to each other in the range of less than 10 milliseconds (ms), and particularly preferably less than 250 microseconds (μs), and even more preferably in the range of 1 μs.

[0018] "Time synchronization" here means, within the scope of this application, either that measurements are actually performed simultaneously, or that the measurements are each timestamped so that they can be interpolated to the same moment.

[0019] In an extended embodiment of the method, the time-synchronized signal and / or data can originate from a root measurement module in the region of the blade root of at least one rotor blade. In this extended embodiment, time-synchronized measurements are also detected within the same rotor blade, acquired by blade measurement modules arranged radially spaced apart within the same rotor blade. Finally, in another advantageous design, time-synchronized measurements are performed on at least two, preferably all, rotor blades, wherein at least one root measurement module is arranged in the blade root region for measuring at least vibration and acceleration data, supplemented, if necessary, by blade measurement modules radially spaced apart within the same rotor blade.

[0020] Therefore, this design not only enables the time-synchronous evaluation of vibration and operating conditions measurements via accelerometer and / or gyroscope sensors within a single module, but also allows for measurements at different radial positions within the at least one rotor blade.

[0021] Furthermore, the ability to synchronously detect comparable measurements at different locations within each blade and compare these measurements enables the reliability testing of the measured data or the information and / or events extracted from it.

[0022] In another preferred embodiment of the method, the at least one accelerometer also functions as a vibration sensor. In this case, one and the same sensor can be used for two different measurement tasks. This becomes feasible when the at least one accelerometer covers a wide frequency range. For vibration analysis of blade vibration, frequencies in the range of 0 to 2 kHz are of interest. To determine the operating state, especially those involving the orientation of the rotor blades in space or the operating state related to the orientation of the rotor blades in space, particularly low frequencies up to 0 Hz, i.e., the static condition, is important.

[0023] More preferably, the at least one acceleration sensor measures acceleration values ​​in three spatial directions.

[0024] The device of the type described at the beginning of the invention is characterized in that an acceleration sensor and / or a gyroscope sensor are arranged in or on at least one rotor blade, and an evaluation device is provided for implementing the method described above to analyze the detected vibration. This produces the advantages described in conjunction with the method.

[0025] In an advantageous design of this device, an accelerometer is also used to detect the vibration to be analyzed, and the operating state of the rotor and / or rotor blades is deduced from the measurements of the accelerometer. Alternatively or additionally, a piezoelectric sensor and / or a microphone can be used as vibration sensors to detect solid-borne sounds and / or airborne sounds.

[0026] The accelerometer sensor is preferably a MEMS (Micro Mechanical System) sensor. Such sensors have the advantage of a wide frequency range, extending to static measurements at the limiting frequency of 0 Hz. Static measurements, or measurements at very low frequencies, are important for determining operating conditions. Furthermore, MEMS sensors are maintenance-free, reliable, and allow for high measurement repetition rates. They are also cost-effective. Preferably, acceleration measurements are performed in at least two, particularly preferably three, spatial directions to determine rotor rotational position and blade bending and torsion. A gyroscope sensor, either in place of or attached to the accelerometer sensor, is also preferably a MEMS sensor.

[0027] In another advantageous design of the device, a first measurement module (also referred to below as the root measurement module) is arranged in the region at the root of the at least one rotor blade, the first measurement module having at least one acceleration sensor and / or at least one gyroscope sensor.

[0028] Preferably, the root measurement module is connected to the distributor module via electrical lines for current supply and / or data exchange, the distributor module being arranged in the rotor hub or in one of the rotor blades. More preferably, the root measurement module is arranged in the region of the blade septum, or on the hub side of the blade septum, or in a region directly radially outside the blade septum.

[0029] Especially for the arrangement in the blade root region, current supply or data connection via electrical lines is advantageous. It can be implemented stably and cost-effectively, and there is no concern, at least in the blade root region, about interference radiation and the effects of strong fields (such as those caused by lightning strikes near wind power equipment).

[0030] In another advantageous design of the device, at least one second measurement module is arranged inside the at least one rotor blade. This second measurement module is connected to the root measurement module and is radially spaced apart from the root measurement module within the rotor blade. The second measurement module is also referred to below as the blade measurement module. Preferably, the blade measurement module has at least one additional accelerometer sensor and / or at least one additional gyroscope sensor. More preferably, a field strength sensor, such as an induction coil and / or a magnetic field sensor, may be provided to detect and acquire strong field strength changes caused by lightning strikes, accompanied by induced voltage and magnetic field, in the environment surrounding the wind power equipment.

[0031] Preferably, the at least one blade measurement module is connected to the root measurement module via at least one optical fiber, wherein the at least one optical fiber enables the power supply to the blade measurement module and / or the data connection between the blade measurement module and the root measurement module. It may be specified that the root measurement module includes a radiation source, particularly a light-emitting diode (LED) or a semiconductor laser, and the blade measurement module includes a photovoltaic cell that converts light received through the optical fiber into current, which is used to operate the blade measurement module. Furthermore, a power storage unit may be included in the blade measurement module to collect the transmitted energy and pulse-operate the energy-intensive components of the blade measurement module.

[0032] Furthermore, measuring acceleration values ​​at different radially spaced locations within the at least one rotor blade allows for the determination of the rotor blade's torsion. Based on the time synchronization of the measurements, for example, it can be determined whether the blade tip is leading or lagging behind the blade root, which allows for the calculation of the load torque in the rotor's rotational direction.

[0033] In another advantageous design of the device, the root measurement module may, if necessary, exist in at least two, preferably all, rotor blades along with at least one blade measurement module. Preferably, the current supply to the root measurement module and thus the blade measurement module is provided jointly by a distributor module arranged in the hub or one of the rotor blades.

[0034] Data collection from the root measurement modules of different rotor blades, and, if necessary, the blade measurement modules, is preferably also performed through a common distributor module. From this distributor module, data is routed via wired data lines, particularly Ethernet lines, and especially preferably single-pair Ethernet (SPE) lines, and, if necessary, via Power over Ethernet (PoE) to another computing unit located inside or outside the wind turbine. It can be specified that complete data processing has already been performed in the distributor module. Alternatively, it can be specified that data preprocessing and, if necessary, time synchronization are performed in the distributor module, and the preprocessed data is then forwarded to the other computing unit. This other computing unit can also be physically located at a different location from within the wind turbine.

[0035] Advantageously, the distributor module outputs a signal to synchronize the time of different root measurement modules, and thus also the blade measurement modules. Alternatively, radio signals, especially GPS (Global Positioning System) signals, can be used for time-synchronized measurements or sufficiently accurate timestamps can be provided to interpolate the time-synchronized measurements. Therefore, time synchronization exists not only for measuring different parameters (vibration, acceleration) within a single module (root measurement module or blade measurement module), but also for modules within a single rotor blade and for measurements performed on different rotor blades. The time synchronization of measurements performed on different rotor blades also allows the derivation of information about the load state and rotational position of each rotor blade.

[0036] The described apparatus and method can be used, for example, to determine the following information or parameters:

[0037] - Wind speed and direction across the entire rotor

[0038] - Monitor powertrain torsion

[0039] - Identify vibration types (blade natural frequency, rotor natural frequency)

[0040] - Icing on rotor blades

[0041] - Input for the icing distribution model

[0042] - Individual blade rotation angles (pitch) are controlled by calculating actual and desired control parameters in real time, which are then transmitted to the pitch controller without delay (only for redundancy verification when necessary).

[0043] - Rotor Modeling

[0044] - Determine the wind field for subsequent rotor blades, for example, in the tower.

[0045] - "Errosions Index": Acoustic assessment, based on noise level / spectrum of operating parameters.

[0046] - Input for rotor / blade lifespan model and digital twin.

[0047] - Analyze instantaneous operating states that cannot be discerned from the operating data of the device controller. Attached Figure Description

[0048] The invention will now be described in detail with reference to an embodiment and the accompanying drawings. In the drawings:

[0049] Figure 1 A spatial view showing a portion of the wind power equipment;

[0050] Figure 2 Showing the use of Figure 1 A schematic diagram of a device for monitoring the condition of rotor blades in wind power equipment; and

[0051] Figure 3 Show Figure 2 A more detailed schematic diagram of the implementation scheme of one branch of the device. Detailed Implementation

[0052] In the accompanying drawings, the same reference numerals denote elements that have the same or the same function. For clarity, not all elements in all drawings are given reference numerals.

[0053] Figure 1 First, the upper portion of the wind power unit 1 is shown as an example, in which the nacelle 3 is rotatably arranged on the tower 2. A rotor 4, having a hub 5 and three rotor blades 6, is substantially rotatable about a horizontal axis and supported on the nacelle 3. In the nacelle 3, a power transmission system having a drive unit and a generator is supported downstream of the rotor 4.

[0054] To specifically monitor the condition of the rotor blades 6, a device is provided in the rotor 4, which includes a first measurement module 10 (root measurement module 10) and a second measurement module 20 (blade measurement module 20) in each rotor blade 6. A distributor 30 is arranged in the hub 5 of the rotor 4, which provides energy to the modules 10 and 20 in the rotor blades 6 and collects and forwards the measurement data of the modules 10 and 20.

[0055] For this purpose, an electrical line 31 for energy and data is routed from the distributor 30 to the root measurement module 10. In the illustrated embodiment, an optical fiber 32 extends from the root measurement module 10 to the blade measurement module 20, through which energy in the form of light is routed from the root measurement module 10 to the blade measurement module 20 to supply the blade measurement module, and data is transmitted bidirectionally. In this way, the blade measurement module 20 can be connected deep within the rotor blade 6 without the risk of high voltage in the power supply line, such as due to lightning induction, which could damage the blade measurement module 20 itself or the components connected to it. "Deep within" the rotor blade here means, for example, at one-third of the length of the rotor blade 6 or even at the blade tip.

[0056] Figure 2 The arrangement of the root measurement module 10, the blade measurement module 20, and the distributor 30 is shown schematically again.

[0057] In the example shown, the root measurement module 10 is positioned directly behind the blade septum 7. Alternatively, it can be positioned near the front of the blade septum 7 when viewed from the hub 5.

[0058] As previously mentioned, line 31 extends from distributor 30 to root measurement module 10. Energy and data are transmitted from each root measurement module 10 to its associated blade measurement module 20 via at least one optical fiber 32. For this purpose, a transmitter 13 is arranged in each root measurement module 10, which feeds light into the at least one optical fiber 32. This transmitter may be a high-power LED or a semiconductor laser. Each blade measurement module 20 includes a receiver for the light, which has a photovoltaic cell 23 that converts the light back into electrical energy. A DC-DC voltage converter is connected downstream of the photovoltaic cell 23 to provide operating voltage to the blade measurement module 20.

[0059] For data transmission, each root measurement module 10 and each blade measurement module 20 is equipped with an additional transceiver, which includes a transmitter and a receiver, respectively. Data transmission can be carried out through the same optical fiber 32, through which energy is also transmitted, or alternatively through separate optical fibers 32.

[0060] Data transmitted from the blade measurement module 20 to the root measurement module 10 is then forwarded from there to the distributor 30. If the wind power unit 1 supports wired data transmission between the nacelle 3 and the hub 5, then all data can be output by the distributor 30 via a wired connection through interface 33. Alternatively, radio transmission from the distributor 30 to a receiver in the nacelle 3 can be designed. Interface 33 can be used for both data and energy transmission and can be configured, for example, as a PoE (Power over Ethernet) interface. If data transmission is wireless, interface 33 can also be used solely for energy supply.

[0061] To enable time-synchronized measurements across different modules 10 and 20, or to provide sufficiently accurate timestamps that allow interpolation to the same moment, the distributor can output a time signal to the root measurement module 10 and indirectly to the blade measurement module 20. Alternatively, another time base, available at appropriate accuracy across all modules 10 and 20, such as a GPS signal, can be used.

[0062] Each root measurement module 10 and each blade measurement module 20 includes at least one accelerometer sensor 11 or 21 for measuring acceleration values. In the illustrated embodiment, the accelerometer sensor 11 or 21 is a MEMS sensor that detects acceleration values ​​in three dimensions and over a wide frequency range within a compact housing. In this embodiment, the accelerometer sensors 11 and 21 provide not only vibration data at higher frequencies but also acceleration values ​​at low frequencies up to 0 Hz, which are used to determine the operating state of the rotor 4 and rotor blades 6. This operating state relates, for example, to the rotational position of the rotor 4 and therefore to the basic orientation of the rotor blades 6. Furthermore, the operating state can be the axial rotational position (pitch angle) and / or axial torsion and / or bending of the rotor blades 6. The load on the rotor blades 6 can be derived from bending.

[0063] To acquire solid-state sound, piezoelectric sensors can be used additionally, for example, while airborne sound can be acquired additionally, for example, using capacitor microphones, electromagnetic microphones, and / or MEMS microphones.

[0064] Furthermore, in the illustrated example, each root measurement module 10 and each blade measurement module 20 includes a gyroscope sensor 12 or 22, which can be used, either as an adjunct or alternative, to the corresponding accelerometer sensor 11, 21 for determining the operating status.

[0065] Figure 3 schematically shown Figure 2One branch of the device, namely, in a feasible embodiment, one of the rotor blades 6, the distributor 30 and the root measurement module 10 or the blade measurement module 20.

[0066] exist Figure 3 In the illustrated embodiment, the root measurement module 10 and the blade measurement module 20 each have MEMS circuit boards 17 and 27, which can accommodate up to two MEMS modules 18 and 28, respectively. In the root measurement module 10, in one design, the MEMS circuit board 17 may be equipped with only one MEMS module 18, which includes the aforementioned accelerometer sensor 11 and gyroscope sensor 12. Here, the accelerometer sensor 11 can have a sufficiently high time resolution to detect frequencies up to a few kHz and thus also function as a vibration sensor.

[0067] The blade measurement module 20 has a similar MEMS module 28, which includes an accelerometer sensor 21. Additionally, a second MEMS module 28 with a gyroscope sensor 22 is used here, by way of example. Alternatively, separate MEMS modules 18 may be used for the accelerometer sensor 11 and the gyroscope sensor 12 in the root measurement module 10. Likewise, conversely, only one MEMS module 28 may be used in the blade measurement module 20, which includes an accelerometer sensor 21 integrated with the gyroscope sensor 22.

[0068] MEMS circuit boards 17 and 27 are connected to control circuit boards 14 and 24 of the root measurement module or blade measurement module 10 and 20 via buses 16 and 26, respectively. Control circuit boards 14 and 24 include processors and / or FPGAs (Field Programmable Gate Arrays) for controlling and processing data of the respective modules 10 and 20. A transmitter 13, or photovoltaic cell 23, is also arranged on control circuit boards 14 and 24 for transmitting energy via optical fiber 32.

[0069] Both modules 10 and 20 have a microphone 15 as an additional sensor for collecting airborne sound. For example, it can be specified that the rotor blade 6 provides the user with "sound samples" for acoustically assessing the condition of the wind power equipment 1. In addition to this manual acoustic assessment, automated assessment can also be performed using spectral analysis of the signal from the microphone 15, especially with the aid of learning algorithms when using pattern recognition.

[0070] The two modules 10 and 20 can also include additional sensors, such as those for temperature measurement. In this way, the provided infrastructure is comprehensive for all information to be detected within the rotor blades 6, for energy supply and data transmission.

[0071] In addition, the blade measurement module 20 includes an induction coil 29 as an electric field strength sensor for detecting lightning strikes in the environment surrounding the wind power equipment 1. Alternatively or additionally, a sensor for measuring the magnetic field, such as a Hall sensor, can be provided, which can also detect lightning strikes.

[0072] like Figure 3 As further shown, in this implementation scheme, a controller 34 with a processor and / or FPGA is also provided in the distributor 30. Data and energy are distributed to three interfaces 36 via a data and energy distributor bus 35, in particular an SPE bus with PoE, on which, exemplarily, only one branch for one of the rotor blades 6 is connected.

[0073] Figure Labels

[0074] 1 Wind power equipment

[0075] 2 towers

[0076] 3 cabins

[0077] 4 rotors

[0078] 5 hub components

[0079] 6 rotor blades

[0080] 7-blade septum

[0081] 10. First Measurement Module (Root Measurement Module)

[0082] 11 Accelerometers

[0083] 12 gyroscope sensors

[0084] 13 transmitters

[0085] 14 Control Circuit Boards

[0086] 15 microphones

[0087] 16-bus

[0088] 17MEMS circuit board

[0089] 18 MEMS module

[0090] 20. Second Measurement Module (Blade Measurement Module)

[0091] 21 accelerometers

[0092] 22 Gyroscope Sensors

[0093] 23 photovoltaic cells

[0094] 24 control circuit boards

[0095] 25 microphones

[0096] 26 bus

[0097] 27MEMS circuit board

[0098] 28 MEMS modules

[0099] 29 Induction Coils

[0100] 30 Distributor

[0101] 31 power lines

[0102] 32 fiber optic

[0103] 33 interface

[0104] 34 controllers

[0105] 35 Data and Energy Distributor Bus

[0106] 36 interfaces

Claims

1. A method for monitoring the state of a wind power device (1) by means of analyzing the vibration of at least one rotor blade (6) of the rotor (4) of the wind power device (1), the method comprising the steps of: - The vibration of the at least one rotor blade (6) is detected by means of at least one vibration sensor arranged in or on the rotor blade (6); - Detect at least one acceleration value and / or rotational speed value at at least one location of an acceleration sensor (11, 21) and / or a gyroscope sensor (12, 22) arranged in or on the rotor blade (6); - Determine the operating state of the rotor (4) and / or the rotor blades (6) based on the at least one acceleration value and / or rotational speed value; - Analyze the vibration of at least one rotor blade (6) while taking into account the operating state of the rotor (4) and / or the rotor blade (6).

2. The method according to claim 1, wherein, The operating state relates to the rotational position of the rotor (4).

3. The method according to claim 1 or 2, wherein, The operating state involves the axial rotational position and / or axial torsion and / or bending of the rotor blade (6).

4. The method according to claim 3, wherein, The operating state involves a bending moment at the root of the rotor blade (6), which is determined based on the bending of the rotor blade (6).

5. The method according to any one of claims 1 to 4, wherein, The information from the at least one vibration sensor and the information from the at least one acceleration sensor (11, 21) and / or the at least one gyroscope sensor (12, 22) are detected and evaluated synchronously with each other in time.

6. The method according to any one of claims 1 to 5, wherein, The at least one acceleration sensor (11, 21) is also used as a vibration sensor.

7. The method according to any one of claims 1 to 6, wherein, The at least one acceleration sensor (11, 21) measures acceleration values ​​in three spatial directions.

8. A device for monitoring the status of a wind power equipment (1), the device having at least one vibration sensor disposed in or on at least one rotor blade (6) of the wind power equipment (1) for detecting vibration of the at least one rotor blade (6), characterized in that, An acceleration sensor (11, 21) and / or a gyroscope sensor (12, 22) are arranged in or on the rotor blade (6), and an evaluation device is provided for implementing the method according to any one of claims 1 to 7 for analyzing the detected vibration.

9. The apparatus according to claim 8, wherein, The acceleration sensors (11, 21) are used to detect vibrations.

10. The apparatus according to claim 8 or 9, wherein, At least two rotor blades, preferably all rotor blades (6) of the wind power equipment (1) have at least one accelerometer (11, 21) and / or gyroscope (12, 22).

11. The apparatus according to any one of claims 8 to 10, wherein, In the at least one rotor blade (6), a first measurement module (10) is arranged in the region at the root of the blade, the first measurement module having the at least one acceleration sensor (11, 21) and / or the at least one gyroscope sensor (12, 22).

12. The apparatus according to claim 11, wherein, The first measurement module (10) is connected to the distributor (30) via an electrical line (31) for current supply and / or for data exchange, which is arranged in the hub (5) of the rotor (4).

13. The apparatus according to claim 11 or 12, wherein, The first measurement module (10) is arranged in the area of ​​the blade septum (7).

14. The apparatus according to any one of claims 11 to 13, characterized in that, At least one second measuring module (20) is arranged inside the at least one rotor blade (6), the second measuring module being connected to the first module (10) and positioned radially spaced apart from the first module (10) in the rotor blade (6).

15. The apparatus according to claim 14, wherein, The at least one second measurement module (20) has at least one additional accelerometer sensor (21) and / or at least one additional gyroscope sensor (22).

16. The apparatus according to claim 14 or 15, wherein, The at least one second measurement module (20) includes a field strength sensor, particularly an induction coil (29) and / or a magnetic field strength sensor.

17. The apparatus according to any one of claims 12 to 16, wherein, The distributor (30) is configured to output a signal for time synchronization to each first measurement module (10) and optionally each at least one second measurement module (20).

18. The apparatus according to any one of claims 14 to 17, wherein, The at least one second measurement module (20) is connected to the first measurement module (10) via at least one optical fiber (32), wherein the at least one optical fiber (32) enables the energy supply of the at least one second measurement module (20) and / or the data connection between the at least one second measurement module (20) and the first measurement module (10).

19. The apparatus according to any one of claims 8 to 18, wherein, The at least one accelerometer sensor (11, 21) and / or the at least one gyroscope sensor (12, 22) are MEMS sensors.

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