A method for identifying the installation state of a wind turbine vibration sensor

Abstract

The application relates to a wind turbine vibration sensor installation state recognition method, comprising the following steps: acquiring multiple groups of operation data of a wind turbine during shutdown, each group of operation data comprising at least a first vibration acceleration along the front-rear direction of a nacelle and a second vibration acceleration along the left-right direction of the nacelle; filtering and integrating the first vibration acceleration and the second vibration acceleration respectively to obtain corresponding first vibration speed and second vibration speed; constructing a vibration speed evaluation index according to the first vibration speed and the second vibration speed, and constructing a vibration acceleration evaluation index according to the first vibration acceleration and the second vibration acceleration; and determining whether the installation direction of the vibration sensor is correct according to the vibration speed evaluation index and the vibration acceleration evaluation index. Therefore, whether the direction of the vibration sensor is correct can be automatically recognized through the shutdown data of the wind turbine after the hoisting of the wind turbine is completed.

Description

Technical Field

[0001] This application relates to the field of wind power generation, and in particular to a method for identifying the installation status of a vibration sensor for a wind turbine. Background Technology

[0002] During actual operation, wind turbines experience significant vibrations due to wind loads, asymmetrical installation, rotor rotation, and yaw, which can affect the quality and lifespan of components such as bearings, gearboxes, and couplings. The nacelle, located at the top of the tower and connected to the blades via the hub, is the part of the wind turbine experiencing the most vibration.

[0003] To protect the equipment within wind turbine units, most systems currently install vibration acceleration sensors inside the nacelle to detect vibration and trigger alarms or shutdowns. These sensors typically measure vibration data in the horizontal X-axis (front-to-back direction of the nacelle) and Y-axis (left-to-right direction of the nacelle). However, during actual wind turbine installation, it's common for the sensors to be installed in reverse or for the vibration polarity to be abnormal (caused by reversed sensor polarity). This not only affects the analysis of the unit's operating status but also leads to errors in vibration-based control. Therefore, correctly identifying nacelle vibration signals is crucial for the stable operation of wind turbine units. Summary of the Invention

[0004] In view of the above-mentioned problems of the prior art, this application provides a method for identifying the installation status of vibration sensors in wind turbine units, which can automatically identify whether the direction and polarity of the vibration sensors are correct based on the unit shutdown data after the wind turbine unit is hoisted.

[0005] To achieve the above objectives, the first aspect of this application provides a method for identifying the installation status of a vibration sensor for a wind turbine, comprising: acquiring multiple sets of operating data of the wind turbine during shutdown, each set of operating data including at least a first vibration acceleration along the front-to-back direction of the nacelle and a second vibration acceleration along the left-to-right direction of the nacelle; filtering and integrating the first vibration acceleration and the second vibration acceleration respectively to obtain corresponding first vibration rate and second vibration rate; constructing a vibration rate evaluation index based on the first vibration rate and the second vibration rate, and constructing a vibration acceleration evaluation index based on the first vibration acceleration and the second vibration acceleration; and determining whether the installation orientation of the vibration sensor is correct based on the vibration rate evaluation index and the vibration acceleration evaluation index.

[0006] As described above, this application processes the collected vibration acceleration data into vibration rate data, constructs a vibration rate evaluation index based on the vibration rate data, and constructs a vibration acceleration evaluation index based on the vibration acceleration rate. Based on the vibration rate evaluation index and the vibration acceleration evaluation index, it determines whether the installation direction of the vibration sensor is correct. This enables the identification of the installation direction and polarity of the vibration sensor through data-driven means after the wind turbine is installed, thereby ensuring the stable operation of the wind turbine.

[0007] As one possible implementation of the first aspect, the step of filtering and integrating the first vibration acceleration and the second vibration acceleration to obtain the corresponding first vibration rate and second vibration rate includes: performing bandpass filtering on the first vibration acceleration and the second vibration acceleration with the first-order frequency of the wind turbine tower as the passband center to obtain the filtered first vibration acceleration and the filtered second vibration acceleration; integrating the filtered first vibration acceleration and the filtered second vibration acceleration to obtain the corresponding first initial vibration rate and the second initial vibration rate; and performing error elimination on the first initial vibration rate and the second initial vibration rate based on the least squares method to obtain the first vibration rate and the second vibration rate.

[0008] As shown above, bandpass filtering can remove interference from other irrelevant frequency signals, ensuring signal purity; integration can convert vibration acceleration signals into vibration velocity signals, and error elimination can be performed on the vibration velocity signals, thus ensuring the accuracy of the final vibration velocity.

[0009] As one possible implementation of the first aspect, the step of constructing a vibration rate evaluation index based on the first vibration rate and the second vibration rate includes: obtaining a first negative velocity minimum of the first vibration rate within a preset time window before shutdown and a second negative velocity minimum of the first vibration rate within the preset time window after shutdown, and calculating the ratio of the second negative velocity minimum to the first negative velocity minimum to obtain a first velocity ratio; obtaining a third negative velocity minimum of the second vibration rate within the preset time window before shutdown and a fourth negative velocity minimum of the second vibration rate within the preset time window after shutdown, and calculating the ratio of the fourth negative velocity minimum to the third negative velocity minimum to obtain a second velocity ratio; and constructing the vibration rate evaluation index based on the first velocity ratio and the second velocity ratio.

[0010] As one possible implementation of the first aspect, constructing the vibration rate evaluation index based on the first rate ratio and the second rate ratio includes: determining the vibration rate evaluation index according to the following formula. :

[0011]

[0012] in, This is the first rate ratio. This is the second rate ratio.

[0013] As one possible implementation of the first aspect, the step of constructing a vibration acceleration evaluation index based on the first vibration acceleration and the second vibration acceleration includes: obtaining the minimum value of a first negative acceleration of the first vibration acceleration within a preset time window before shutdown, and the minimum value of a second negative acceleration of the first vibration acceleration within the preset time window after shutdown, and calculating the ratio of the minimum value of the second negative acceleration to the minimum value of the first negative acceleration to obtain a first acceleration ratio; obtaining the minimum value of a third negative acceleration of the second vibration acceleration within the preset time window before shutdown, and the minimum value of a fourth negative acceleration of the second vibration acceleration within the preset time window after shutdown, and calculating the ratio of the minimum value of the fourth negative acceleration to the minimum value of the third negative acceleration to obtain a second acceleration ratio; and constructing the vibration acceleration evaluation index based on the first acceleration ratio and the second acceleration ratio.

[0014] As one possible implementation of the first aspect, constructing the vibration acceleration evaluation index based on the first acceleration ratio and the second acceleration ratio includes: determining the vibration acceleration evaluation index according to the following formula. :

[0015]

[0016] in, The acceleration ratio is... This is the second acceleration ratio.

[0017] As one possible implementation of the first aspect, determining whether the installation direction of the vibration sensor is correct based on the vibration rate evaluation index and the vibration acceleration evaluation index includes: assigning weighting coefficients to the vibration rate evaluation index and the vibration acceleration evaluation index respectively and performing weighted calculations to obtain an installation direction identification index; and determining whether the installation direction of the vibration sensor is correct based on the installation direction identification index.

[0018] As shown above, by assigning different weighting coefficients to the vibration rate assessment index and the vibration acceleration assessment index, the confidence level of both can be defined. This allows the final identification index to be adaptively adjusted according to different working conditions, meeting the different needs of various working conditions.

[0019] As one possible implementation of the first aspect, determining whether the installation direction of the vibration sensor is correct based on the installation direction identification index includes: if the installation direction identification index is greater than 0, then the installation direction of the vibration sensor is correct; if the installation direction identification index is not greater than 0, then the installation direction of the vibration sensor is incorrect.

[0020] As one possible implementation of the first aspect, it further includes: when the installation orientation of the vibration sensor is correct: acquiring a first moment corresponding to the minimum negative velocity during the shutdown process and a second moment corresponding to the maximum positive velocity during the shutdown process, and determining whether the signal polarity of the vibration sensor is correct based on the first moment and the second moment.

[0021] As one possible implementation of the first aspect, determining whether the signal polarity of the vibration sensor is correct based on the first time and the second time includes: if the first time is earlier than the second time, then the signal polarity of the vibration sensor is correct; if the first time is not earlier than the second time, then the signal polarity of the vibration sensor is incorrect.

[0022] Therefore, if the vibration sensor is installed in the correct orientation, it is also possible to identify whether the polarity of the vibration sensor is installed correctly.

[0023] A second aspect of this application provides a system for identifying the installation status of a vibration sensor for a wind turbine, comprising: an acquisition module for acquiring multiple sets of operating data of the wind turbine during shutdown, each set of operating data including at least a first vibration acceleration along the front-to-back direction of the nacelle and a second vibration acceleration along the left-to-right direction of the nacelle; a processing module for filtering and integrating the first vibration acceleration and the second vibration acceleration respectively to obtain corresponding first vibration rate and second vibration rate; a construction module for constructing a vibration rate evaluation index based on the first vibration rate and the second vibration rate, and constructing a vibration acceleration evaluation index based on the first vibration acceleration and the second vibration acceleration; and a determination module for determining whether the installation orientation of the vibration sensor is correct based on the vibration rate evaluation index and the vibration acceleration evaluation index.

[0024] The beneficial effects in this regard can also be found in the descriptions of the beneficial effects in each part of the first aspect above.

[0025] A third aspect of this application provides a computer program product, which, when executed on a computer, is used to perform the method for identifying the installation status of a wind turbine vibration sensor as described in any of the first aspects above.

[0026] The beneficial effects in this regard can also be found in the descriptions of the beneficial effects in each part of the first aspect above.

[0027] The fourth aspect of this application provides a computer-readable storage medium having program instructions stored thereon, which, when executed by a computer, cause the computer to perform the method for identifying the installation status of a wind turbine vibration sensor as described in any one of the first aspects above.

[0028] The beneficial effects in this regard can also be found in the descriptions of the beneficial effects in each part of the first aspect above.

[0029] The fifth aspect of this application provides a computing device, comprising: at least one processor; and at least one memory connected to the processor and storing program instructions, which, when executed by the at least one processor, cause the at least one processor to perform the method for identifying the installation status of a wind turbine vibration sensor as described in any of the first aspects above.

[0030] The beneficial effects in this regard can also be found in the descriptions of the beneficial effects in each part of the first aspect above.

[0031] These and other aspects of this application will become more apparent in the description of the following embodiments(s). Attached Figure Description

[0032] The following description, with reference to the accompanying drawings, further illustrates the various features of this application and the relationships between them. The drawings are exemplary; some features are not shown to scale, and some drawings may omit conventional features in the field of this application that are not essential to it, or additional features that are not essential to this application may be shown. The combination of features shown in the drawings is not intended to limit this application. Furthermore, throughout this specification, the same reference numerals refer to the same things. Specific descriptions of the drawings are as follows:

[0033] Figure 1 This is a schematic diagram of the unit coordinate direction provided in the embodiments of this application;

[0034] Figure 2a A schematic diagram of the pitch angle changing over time, provided for an embodiment of this application;

[0035] Figure 2b A schematic diagram of the thrust in the X direction of a stationary hub versus time, provided for an embodiment of this application;

[0036] Figure 2c The schematic diagram of the curves provided in the embodiments of this application is provided for the purposes of this application.

[0037] Figure 3A first flowchart illustrating a method for identifying the installation status of a vibration sensor in a wind turbine generator, provided in an embodiment of this application.

[0038] Figure 4 A second flowchart illustrating a method for identifying the installation status of a vibration sensor in a wind turbine generator, provided in an embodiment of this application;

[0039] Figure 5 A schematic diagram of a wind turbine vibration sensor installation status identification system provided in this application embodiment;

[0040] Figure 6 This is a schematic diagram of the structure of a computing device provided in an embodiment of this application. Detailed Implementation

[0041] The technical solutions provided in this application will be further described below with reference to the accompanying drawings and embodiments. It should be understood that the solutions provided in the embodiments of this application are mainly for illustrating possible implementations of the technical solutions of this application and should not be construed as the sole limitation on the technical solutions of this application. Those skilled in the art will recognize that, with the evolution of technology, the technical solutions provided in this application are equally applicable to similar technical problems.

[0042] It should be understood that this application provides a scheme for identifying the installation status of a vibration sensor for a wind turbine. Since these technical solutions solve problems based on the same or similar principles, some repetitive details may not be repeated in the following descriptions of specific embodiments. However, these specific embodiments should be considered as mutually referencing each other and can be combined with each other.

[0043] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. In case of any inconsistency, the meaning set forth in this specification or derived from the content described herein shall prevail. Furthermore, the terminology used herein is for the purpose of describing embodiments of this application only and is not intended to limit the scope of this application.

[0044] Before introducing the specific implementation methods of this application, it should be noted that, for ease of description, the following text will use the following terms: Figure 1 As shown, the direction along the fore-and-aft of the cabin is referred to as the X direction (i.e., Figure 1 The XT deployed from the center will be referred to as the Y-direction along the left-right direction of the cabin (i.e., Figure 1 The X direction refers to the direction along the main shaft of the wind turbine and pointing towards the tail of the nacelle, while the Y direction refers to the horizontal direction perpendicular to the main shaft of the wind turbine (i.e., the horizontal direction perpendicular to the X direction). The X and Y directions are perpendicular to each other.

[0045] The following is combined Figures 2a-2cThe principles of this application will be introduced.

[0046] During wind turbine shutdown, the continuous increase in blade pitch angle effectively reduces the thrust on the turbine. As the thrust decreases, the nacelle will move significantly in the negative X direction (i.e., along the front-to-back direction of the nacelle and pointing towards the front of the nacelle), while the displacement in the Y direction is relatively gradual. This physical phenomenon can be verified using simulation tools (such as Bladed) or field measurement data.

[0047] like Figures 2a-2c As shown, Figure 2a The curve representing the change in the blade 1 pitch angle (deg) over time should be understood as follows: typically, all three blades move synchronously. Figure 2a The pitch angle of all three blades can be represented by the pitch angle of the first blade. Figure 2a It can be seen that the pitching begins at around 25 seconds. Figure 2b The curve representing the change in thrust (Stationary hub FX [kN]) in the X direction over time is given by... Figure 2b It can be seen that the thrust drops rapidly at around 25 seconds. Figure 2c The curves represent the change of cabin displacement over time. Curve A represents the change of cabin displacement in the X direction (Nacelle fore-aft displacement) over time, and curve B represents the change of cabin displacement in the Y direction (Nacelle side-side displacement) over time. Figure 2c It can be seen that after approximately 25 seconds, the displacement in the X direction changes significantly in the negative direction, while the displacement in the Y direction changes relatively gradually. Therefore, the installation direction and polarity of the vibration sensor are identified based on the displacement changes in the X and Y directions of the nacelle during shutdown. It should be understood that the displacement changes in the X and Y directions of the nacelle can be represented by velocity, but in actual wind turbine sites, only the vibration acceleration signal of the nacelle can be obtained through vibration sensors installed on the nacelle. It is not possible to directly obtain the displacement and velocity signals of the nacelle. Therefore, the solution provided in this application converts the obtained vibration acceleration signal of the nacelle into vibration velocity during actual implementation, and then performs the subsequent identification process based on the vibration velocity.

[0048] The following section provides a detailed description of a method for identifying the installation status of a vibration sensor for a wind turbine, based on an embodiment of this application, with reference to the accompanying drawings.

[0049] like Figure 3The above is a flowchart of a method for identifying the installation status of a vibration sensor for a wind turbine provided in an embodiment of this application. The implementation process of this method mainly includes steps S110-S140, which will be described in turn below.

[0050] S110: Acquire multiple sets of operating data of the wind turbine during the shutdown process. Each set of operating data includes at least a first vibration acceleration along the front-to-back direction of the nacelle and a second vibration acceleration along the left-to-right direction of the nacelle.

[0051] In this embodiment, the operational data can be collected during normal shutdown processes and / or during abnormal shutdown processes (such as emergency shutdowns due to unforeseen circumstances). As one implementation method, the parameters for sampling this operational data can be set as follows: a sampling period of 0.01s, a sampling duration of 60s before and after shutdown, and a minimum of 10 samples.

[0052] In some embodiments, each set of operating data may include, in addition to the first and second vibration accelerations mentioned above, controller status bits and / or pitch commands and angles. The controller status bits represent control signals indicating the current operating state of the wind turbine. These are output by the main control system; for example, status bit 0 indicates standby, status bit 1 indicates startup, status bit 2 indicates normal power generation, status bit 3 indicates normal shutdown, and status bit 4 indicates emergency shutdown. Based on the changes in these controller status bits, the data acquisition period can be accurately determined, such as the acquisition duration being the 60 seconds before and after shutdown. By acquiring the point of change from status 2 (normal power generation) to status 3 (normal shutdown) or status 4 (emergency shutdown), the shutdown start time t can be determined. Based on this shutdown start time t, the operating data for the 60 seconds before and after shutdown can be accurately obtained. The pitch command is the target pitch angle output by the controller. The pitch angle is the real-time angle actually reached by the blades. The pitch command and angle can be used to verify the authenticity of the shutdown process, thereby eliminating abnormal data. For example, if the controller status bit shows a shutdown state, but the actual pitch angle does not increase significantly, the data collected at this time can be considered abnormal and should be discarded.

[0053] S120: Filter and integrate the first vibration acceleration and the second vibration acceleration respectively to obtain the corresponding first vibration rate and second vibration rate.

[0054] The vibration acceleration signal of a wind turbine often contains multiple frequency signals, such as the first-order frequency of the tower and the 3P rotational frequency of the rotor. Therefore, this step first requires filtering the first and second vibration accelerations separately to remove the influence of irrelevant frequencies and extract the vibration signal related to the first-order frequency of the tower. Specifically: using the first-order frequency of the wind turbine tower as the passband center, bandpass filtering is performed on the first and second vibration accelerations respectively to obtain the filtered first and second vibration accelerations.

[0055] As one implementation method, the bandpass filter can be performed using the following formula: Bandpass filtering is applied to the first vibration acceleration and the second vibration acceleration respectively using the following formula:

[0056]

[0057] In the above formula, Indicates passband gain. This represents the quality factor (damping ratio). This represents the center angular frequency of the passband (rad / s), which is obtained by converting it from the first-order frequency of the tower. Represents the complex frequency variable in the Laplace transform. This represents the time constant.

[0058] After obtaining the filtered first vibration acceleration and the filtered second vibration acceleration using the above formula, the filtered first vibration acceleration and the filtered second vibration acceleration are integrated respectively to obtain the first initial vibration rate corresponding to the first vibration acceleration and the second initial vibration rate corresponding to the second vibration acceleration.

[0059] As one implementation method, vibration acceleration can be converted into vibration velocity through discretization integration. Specifically, this integration process can be performed using the following formula: Integrate the first vibration acceleration and the second vibration acceleration respectively using the following formula:

[0060]

[0061] In the above formula, Represents the vibration rate at time k. express The vibration rate at time t, This represents the vibration acceleration at time k. This indicates the sampling period (e.g., 0.01s).

[0062] It should be understood that if the original signals before integration (the filtered first vibration acceleration and the filtered second vibration acceleration) have slight deviations (such as deviations caused by sensor zero-point drift or low-frequency noise), these errors will accumulate with each integration operation, resulting in a linearly increasing error in the final integration result over time. Therefore, to eliminate this error, this embodiment, after obtaining the first and second initial vibration velocities, can further perform error elimination on the first and second initial vibration velocities using the least squares method, thereby obtaining the final first and second vibration velocities, making the integration result more accurate and reasonable.

[0063] As one implementation method, the least squares-based error elimination process can be performed using the following formula: Error elimination is performed on the first initial vibration rate and the second initial vibration rate respectively using the following formula:

[0064]

[0065] in, , , Using the least squares method, we can obtain the following: The vibration rate after eliminating errors is further obtained as follows: That is, by subtracting the fitted error trend from the original velocity, the accurate vibration velocity can be obtained. In the above formula, The vibration rate is indicated (in this embodiment, it refers to the first initial vibration rate or the second initial vibration rate). Represents a time sequence, express The vibration rate at time t, express The vibration rate at time t, This represents the constant term in the fit, i.e., the intercept. This represents the coefficient, i.e., the slope. This indicates a linear trend error signal.

[0066] The final first vibration rate and the second vibration rate are obtained from the above formula.

[0067] S130: Construct a vibration rate evaluation index based on the first vibration rate and the second vibration rate, and construct a vibration acceleration evaluation index based on the first vibration acceleration and the second vibration acceleration.

[0068] Wherein, the first vibration rate represents the vibration rate in the X direction, the second vibration rate represents the vibration rate in the Y direction, the first vibration acceleration represents the vibration acceleration in the X direction, and the second vibration acceleration represents the vibration acceleration in the Y direction.

[0069] In some embodiments, the process of constructing vibration rate assessment indices specifically includes:

[0070] The minimum negative velocity within a preset time window (e.g., within 7 seconds before shutdown) before the wind turbine shutdown is obtained from the first vibration velocity data (i.e., vibration velocity in the X direction) as the first minimum negative velocity value minFAVeBefore. The minimum negative velocity within a preset time window after the wind turbine shutdown (e.g., within 7 seconds before shutdown) is obtained from the first vibration velocity data as the second minimum negative velocity value minFAVeAfter. The ratio of the second minimum negative velocity value minFAVeAfter to the first minimum negative velocity value minFAVeBefore is calculated to obtain the first velocity ratio FAVERatio, i.e.:

[0071]

[0072] The minimum negative velocity within a preset time window before wind turbine shutdown (e.g., within 7 seconds before shutdown) is obtained from the second vibration velocity data (i.e., vibration velocity in the Y direction) as the third minimum negative velocity value minSSVeBefore. The minimum negative velocity within a preset time window after wind turbine shutdown (e.g., within 7 seconds before shutdown) is obtained from the second vibration velocity data as the fourth minimum negative velocity value minSSVeAfter. The ratio of the fourth minimum negative velocity value minSSVeAfter to the third minimum negative velocity value minSSVeBefore is calculated to obtain the second velocity ratio SSVeRatio, i.e.:

[0073]

[0074] A vibration velocity evaluation index was constructed based on the first velocity ratio FAVERatio and the second velocity ratio SSVeRatio. Specifically, the vibration rate evaluation index can be determined according to the following formula. (This vibration rate assessment index) Essentially, it is an evaluation index targeting the negative aspect of vibration velocity.

[0075]

[0076] In some embodiments, the process of constructing vibration acceleration evaluation indices specifically includes:

[0077] The minimum negative acceleration within a preset time window (e.g., within 7 seconds before shutdown) before the wind turbine shutdown is obtained from the first vibration acceleration data (i.e., vibration acceleration in the X direction) as the first minimum negative acceleration value minFAAccBefore. The minimum negative acceleration within a preset time window after the wind turbine shutdown (e.g., within 7 seconds before shutdown) is obtained from the first vibration acceleration data as the second minimum negative acceleration value minFAAccAfter. The ratio of the second minimum negative acceleration value minFAAccAfter to the first minimum negative acceleration value minFAAccBefore is calculated to obtain the first acceleration ratio FAAccRatio, i.e.:

[0078]

[0079] The minimum negative acceleration within a preset time window (e.g., within 7 seconds before shutdown) before the wind turbine shutdown is obtained from the second vibration acceleration data (i.e., vibration acceleration in the Y direction) as the third minimum negative acceleration value minSSAccBefore. The minimum negative acceleration within a preset time window after the wind turbine shutdown (e.g., within 7 seconds before shutdown) is obtained from the second vibration acceleration data as the fourth minimum negative acceleration value minSSAccAfter. The ratio of this fourth minimum negative acceleration value minSSAccAfter to the third minimum negative acceleration value minSSAccBefore is calculated to obtain the second acceleration ratio SSAccRatio, i.e.:

[0080]

[0081] A vibration acceleration evaluation index is constructed based on the first acceleration ratio FAAccRatio and the second acceleration ratio SSAccRatio. Specifically, the vibration acceleration evaluation index can be determined according to the following formula. (This vibration acceleration evaluation index) Essentially, it is an evaluation index targeting the negative aspect of vibration acceleration.

[0082]

[0083] S140: Determine whether the installation direction of the vibration sensor is correct based on the vibration rate evaluation index and the vibration acceleration evaluation index.

[0084] Vibration rate evaluation index Vibration acceleration evaluation index The installation direction identification index is obtained by assigning weighting coefficients and performing weighted calculations. (This installation direction identification indicator) Essentially, this is an identification indicator for the negative installation direction. Specifically, the installation direction identification indicator can be calculated using the following formula. :

[0085]

[0086] in, Vibration rate evaluation index The weighting coefficients, Vibration acceleration evaluation index The weighting coefficients, and All of these are pre-configured; for example, if there is a high level of confidence in the vibration rate assessment index, then... Setting it to a larger value indicates a higher level of confidence in the vibration acceleration assessment index, thus... Configured to a larger value. In this embodiment, it is preferable to have greater confidence in the vibration rate, therefore... The value is set to greater than The value, for example , .

[0087] Based on the installation direction identification index obtained above To determine if the vibration sensor is installed in the correct orientation: if the installation orientation identification index... If the vibration sensor is considered to be installed in the correct orientation, then the negative signal recognition flag bit SignalTrueFlagNegative can be set to 1; if the installation orientation recognition index... If the vibration sensor is installed in the wrong direction, you can set the negative signal recognition flag bit SignalTrueFlagNegative=0.

[0088] The solution based on the above embodiments of this application enables the identification of the installation direction of the vibration sensor.

[0089] In some embodiments, to further verify the correctness of the above direction identification, evaluation indices for the positive direction of vibration velocity, the positive direction of vibration acceleration, and the positive direction of installation can be constructed. It should be understood that the construction process of the positive indices is based on the same principle as the construction of the negative indices, so it will not be repeated here. The only difference is that all acquired data are positive maximum values. For example, when constructing the evaluation index for the positive direction of vibration velocity, the maximum positive velocity value is used for calculation; when constructing the evaluation index for the positive direction of vibration acceleration, the maximum positive acceleration value is used for calculation. Based on the evaluation indices for the positive directions of vibration velocity and vibration acceleration, the positive direction of installation identification index is obtained. When the vibration sensor installation direction is identified as correct, the positive signal identification flag bit SignalTrueFlagPositive can be set to 1; when the vibration sensor installation direction is identified as incorrect, the positive signal identification flag bit SignalTrueFlagPositive can be set to 0.

[0090] It should be understood that either the positive or negative evaluation indicators mentioned above can be calculated individually, or both can be calculated together to form mutual verification between the data and further ensure accurate identification.

[0091] As one implementation method, the above steps S130-S140 can be repeated based on the sampling data under different operating conditions to obtain the values ​​of the negative signal identification flag and the positive signal identification flag. When the accuracy rate of at least one set of the negative signal identification flag and the positive signal identification flag exceeds the threshold (e.g., 80%), it is considered that the installation direction of the vibration sensor in the X and Y directions of the unit is correct. When the accuracy rate of at least one set of the negative signal identification flag and the positive signal identification flag is lower than the threshold (e.g., 20%), it is considered that the vibration sensor in the X and Y directions of the unit is installed backwards. The signal directions of the two can be interchanged to verify again.

[0092] In this embodiment, when the vibration sensor is identified as being installed in the correct direction, or when it is identified as being installed in the wrong direction but corrected to be in the correct direction, the signal polarity of the vibration sensor can be further identified. This signal polarity is used to assess whether the positive and negative terminals of the vibration sensor are connected correctly. For example, when the cabin moves forward, the vibration sensor should output a positive value, but because the polarity terminals are reversed, it outputs a negative value. The following describes how to automatically identify whether the signal polarity terminals of the vibration sensor are connected correctly when the installation direction of the vibration sensor is correct:

[0093] Obtain the first moment timeMin corresponding to the minimum value of the negative rate of vibration along the front-back direction of the nacelle and the second moment timeMax corresponding to the maximum value of the positive rate of vibration along the front-back direction of the nacelle during the unit shutdown process, and compare the order of the two: If timeMin < timeMax, that is, when the first moment is earlier than the second moment, it is considered that the signal polarity of the vibration sensor is correctly installed, and the polarity identification bit SymbolTrueFlag = 1 is generated; otherwise, it is considered that the signal polarity of the vibration sensor is incorrectly installed, and the polarity identification bit SymbolTrueFlag = 0 is generated.

[0094] As an implementation method, the above vibration sensor signal polarity identification method can be repeatedly executed based on the sampling data under different working conditions to obtain the corresponding polarity identification bits. When the correct rate of the polarity identification bits exceeds the threshold (such as 80%), it is considered that the signal polarity connection of the vibration sensor in the X direction of this unit is correct. If the correct rate does not exceed the threshold (such as 20%), it is considered that the signal polarity of the vibration sensor in the X direction of this unit is reversed.

[0095] Next, refer to Figure 4 to describe the main steps of the method for identifying the installation state of the wind turbine vibration sensor provided by this application. In this embodiment, the implementation of this method mainly includes: collecting operation data during the shutdown process (which can refer to the above step S110), band-pass filtering, and converting the collected vibration acceleration into vibration rate (which can refer to the above step S120), calculating the signal identification bit SignalTrueFlagNegative or SignalTrueFlagPositive, and determining whether the installation direction of the vibration sensor is correct based on the recognition correct rate (which can refer to the above steps S130 - S140). When the installation direction of the vibration sensor is correct, the polarity identification bit SymbolTrueFlag can also be calculated, and it can be determined whether the polarity terminal connection of the vibration sensor is correct based on the recognition correct rate (which can refer to the steps of automatically identifying whether the signal polarity terminal of the vibration sensor is correctly connected), thereby realizing the automatic identification of the installation direction and connection polarity of the vibration sensor.

[0096] To verify the effectiveness of the above-mentioned scheme in this application, simulation calculations were performed using Bladed simulation software based on an 8MW wind turbine model. The environmental conditions were set as follows: turbulent wind speed of 15m / s, shutdown rate of 1deg / s, and a total of 8 simulation conditions. The above-mentioned scheme was executed under each condition, resulting in the identification results shown in Table 1 below. The index represents the installation direction identification index. For the negative direction, this index represents the direction identification index obtained based on the negative maximum value of the vibration velocity; for the positive direction, this index represents the direction identification index obtained based on the positive maximum value of the vibration velocity. The identification results show that: in the direction identification based on negative vibration data, 7 sets of data showed that the sensor direction was correctly installed (i.e., the corresponding signal identification flag bit SignalTrueFlagNegative=1), with an identification accuracy rate of 87.5%; in the polarity identification, all 8 sets of data showed correct polarity (i.e., the corresponding SymbolTrueFlag=1), with an identification accuracy rate of 100%. Therefore, it can be determined that the vibration sensor of this unit is correctly installed in the X and Y directions, and the signal polarity connection is correct.

[0097] Table 1. Vibration Sensor Identification Indicators (Simulation Data)

[0098]

[0099] Note: The indicator weights are w1=0.6, w2=0.4.

[0100] To simulate an incorrect installation of the vibration sensor, the vibration velocity signals in the X and Y directions of the original simulation data were interchanged, and the X-direction vibration velocity signal was inverted to simulate a reversed polarity connection. The identification process described in the previous embodiment was repeated, resulting in the identification results shown in Table 2 below. The index represents the installation direction identification index. For the negative direction, this index represents the direction identification index based on the negative maximum value of the vibration velocity; for the positive direction, this index represents the direction identification index based on the positive maximum value of the vibration velocity. The identification results show that: in the direction identification based on the negative vibration data, one set of data indicates that the sensor is installed correctly (i.e., the corresponding signal identification flag bit SignalTrueFlagNegative=1), with an identification accuracy of 12.5%, less than the threshold of 20%; in the polarity identification, all eight sets of data are incorrect (i.e., the corresponding SymbolTrueFlag=0), with an identification accuracy of 0%. Therefore, it can be determined that the vibration sensor of this unit is incorrectly installed in both the X and Y directions, and the signal polarity connection is incorrect.

[0101] Table 2 Vibration Sensor Identification Index Table (Simulation Data)

[0102]

[0103] Another embodiment of this application provides a system for identifying the installation status of vibration sensors in wind turbine generators. This system can be implemented by a software system, a hardware device, or a combination of both. The following will be combined with... Figure 5 Let me introduce the system.

[0104] like Figure 5 As shown, the wind turbine vibration sensor installation status identification system can be logically divided into multiple modules, each with different functions. The function of each module is implemented by a processor in a computing device reading and executing instructions from its memory. For example, the wind turbine vibration sensor installation status identification system 40 includes an acquisition module 410, a processing module 420, a construction module 430, and a determination module 440. The acquisition module 410 acquires multiple sets of operating data from the wind turbine during shutdown. Each set of operating data includes at least a first vibration acceleration along the front-to-back direction of the nacelle and a second vibration acceleration along the left-to-right direction of the nacelle. The processing module 420 filters and integrates the first and second vibration accelerations respectively to obtain corresponding first and second vibration rates. The construction module 430 constructs a vibration rate evaluation index based on the first and second vibration rates, and constructs a vibration acceleration evaluation index based on the first and second vibration accelerations. The determination module 440 determines whether the installation orientation of the vibration sensor is correct based on the vibration rate evaluation index and the vibration acceleration evaluation index.

[0105] It should be noted that the specific implementation of each functional module in this embodiment can be found in the description of the above method embodiment, and will not be repeated in this embodiment.

[0106] Another embodiment of this application provides a computer program product that, when run on a computing device, causes the computing device to execute the wind turbine vibration sensor installation status identification method described in the above embodiments. For specific implementation details in this embodiment, please refer to the descriptions in the above embodiments.

[0107] Figure 6 This is a schematic structural diagram of a computing device 500 provided in an embodiment of this application. This computing device can execute various optional embodiments of the above-described method for identifying the installation status of wind turbine vibration sensors. The computing device can be a terminal, or a chip or chip system within the terminal. Figure 6 As shown, the computing device 500 includes: a processor 510, a memory 520, and a communication interface 530.

[0108] It should be understood that Figure 6 The communication interface 530 in the computing device 500 shown can be used to communicate with other devices, and may specifically include one or more transceiver circuits or interface circuits.

[0109] The processor 510 can be connected to the memory 520. The memory 520 can be used to store the program code and data. Therefore, the memory 520 can be a storage unit inside the processor 510, an external storage unit independent of the processor 510, or a component that includes both the storage unit inside the processor 510 and the external storage unit independent of the processor 510.

[0110] Optionally, the computing device 500 may also include a bus. The memory 520 and communication interface 530 can be connected to the processor 510 via the bus. The bus can be a Peripheral Component Interconnect (PCI) bus or an Extended Industry Standard Architecture (EISA) bus, etc. The bus can be divided into an address bus, a data bus, a control bus, etc. For ease of representation, Figure 6 The symbol is represented by a line without an arrow, but this does not mean that there is only one bus or one type of bus.

[0111] It should be understood that in the embodiments of this application, the processor 510 may be a central processing unit (CPU). The processor may also be other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. The general-purpose processor may be a microprocessor or any conventional processor. Alternatively, the processor 510 may employ one or more integrated circuits to execute relevant programs to implement the technical solutions provided in the embodiments of this application.

[0112] The memory 520 may include read-only memory and random access memory, and provides instructions and data to the processor 510. A portion of the processor 510 may also include non-volatile random access memory. For example, the processor 510 may also store device type information.

[0113] When the computing device 500 is running, the processor 510 executes computer execution instructions stored in the memory 520 to perform any of the operation steps of the above method and any of the optional embodiments thereof.

[0114] It should be understood that the computing device 500 according to the embodiments of this application can correspond to the corresponding subject in executing the methods according to the various embodiments of this application, and the above and other operations and / or functions of each module in the computing device 500 are respectively for implementing the corresponding processes of the methods of this embodiment. For the sake of brevity, they will not be described in detail here.

[0115] Those skilled in the art will recognize that the units and algorithm steps of the various examples described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, or a combination of computer software and electronic hardware. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of this application.

[0116] Those skilled in the art will understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0117] In the several embodiments provided in this application, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be through some interfaces; the indirect coupling or communication connection between apparatuses or units may be electrical, mechanical, or other forms.

[0118] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0119] In addition, the functional units in the various embodiments of this application can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit.

[0120] If the aforementioned functions are implemented as software functional units and sold or used as independent products, they can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, or a portion of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods described in the various embodiments of this application. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0121] This application also provides a computer-readable storage medium storing a computer program thereon, which, when executed by a processor, is used to perform the above-described method, which includes at least one of the schemes described in the above embodiments.

[0122] The computer storage medium in this application embodiment can be any combination of one or more computer-readable media. A computer-readable medium can be a computer-readable signal medium or a computer-readable storage medium. For example, a computer-readable storage medium can be, but is not limited to, an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any combination thereof. More specific examples of computer-readable storage media (a non-exhaustive list) include: an electrical connection having one or more wires, a portable computer disk, a hard disk, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fiber, portable compact disk read-only memory (CD-ROM), optical storage device, magnetic storage device, or any suitable combination thereof. In this document, a computer-readable storage medium can be any tangible medium containing or storing a program that can be used by or in conjunction with an instruction execution system, apparatus, or device.

[0123] Computer-readable signal media may include data signals propagated in baseband or as part of a carrier wave, carrying computer-readable program code. Such propagated data signals may take various forms, including but not limited to electromagnetic signals, optical signals, or any suitable combination thereof. Computer-readable signal media may also be any computer-readable medium other than computer-readable storage media, capable of sending, propagating, or transmitting programs for use by or in connection with an instruction execution system, apparatus, or device.

[0124] The program code contained on a computer-readable medium may be transmitted using any suitable medium, including, but not limited to, wireless, wire, optical fiber, RF, etc., or any suitable combination thereof.

[0125] Computer program code for performing the operations of this application can be written in one or more programming languages ​​or a combination thereof, including object-oriented programming languages ​​such as Java, Smalltalk, and C++, and conventional procedural programming languages ​​such as "C" or similar programming languages. The program code can be executed entirely on the user's computer, partially on the user's computer, as a standalone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving remote computers, the remote computer can be connected to the user's computer via any type of network, including a local area network (LAN) or a wide area network (WAN), or it can be connected to an external computer (e.g., via the Internet using an Internet service provider).

[0126] Note that the above are merely preferred embodiments and the technical principles employed in this application. Those skilled in the art will understand that this application is not limited to the specific embodiments described herein, and various obvious changes, readjustments, and substitutions can be made without departing from the scope of protection of this application. Therefore, although this application has been described in detail through the above embodiments, this application is not limited to the above embodiments, and may include many other equivalent embodiments without departing from the concept of this application, all of which fall within the scope of protection of this application.

Claims

1. A method for identifying the installation status of a vibration sensor in a wind turbine generator set, characterized in that, include: Acquire multiple sets of operating data of the wind turbine during the shutdown process. Each set of operating data includes at least a first vibration acceleration along the front-to-back direction of the nacelle and a second vibration acceleration along the left-to-right direction of the nacelle. The first vibration acceleration and the second vibration acceleration are filtered and integrated respectively to obtain the corresponding first vibration rate and second vibration rate; A vibration rate evaluation index is constructed based on the first vibration rate and the second vibration rate, and a vibration acceleration evaluation index is constructed based on the first vibration acceleration and the second vibration acceleration. The installation orientation of the vibration sensor is determined based on the vibration rate evaluation index and the vibration acceleration evaluation index.

2. The method according to claim 1, characterized in that, The step of filtering and integrating the first vibration acceleration and the second vibration acceleration respectively to obtain the corresponding first vibration rate and second vibration rate includes: Using the first-order frequency of the wind turbine tower as the passband center, the first vibration acceleration and the second vibration acceleration are respectively subjected to bandpass filtering to obtain the filtered first vibration acceleration and the filtered second vibration acceleration. Integrate the filtered first vibration acceleration and the filtered second vibration acceleration respectively to obtain the corresponding first initial vibration velocity and second initial vibration velocity. Errors are eliminated for the first initial vibration rate and the second initial vibration rate using the least squares method, respectively, to obtain the first vibration rate and the second vibration rate.

3. The method according to claim 1, characterized in that, The construction of a vibration rate evaluation index based on the first vibration rate and the second vibration rate includes: The minimum value of the first negative velocity of the first vibration rate within a preset time window before shutdown and the minimum value of the second negative velocity of the first vibration rate within the preset time window after shutdown are obtained, and the ratio of the minimum value of the second negative velocity to the minimum value of the first negative velocity is calculated to obtain the first velocity ratio. Obtain the minimum third negative velocity of the second vibration rate within the preset time window before shutdown, and the minimum fourth negative velocity of the second vibration rate within the preset time window after shutdown, and calculate the ratio of the minimum fourth negative velocity to the minimum third negative velocity to obtain the second velocity ratio. The vibration rate evaluation index is constructed based on the first rate ratio and the second rate ratio.

4. The method according to claim 3, characterized in that, The construction of the vibration rate evaluation index based on the first rate ratio and the second rate ratio includes: The vibration rate evaluation index is determined by the following formula. : ； in, This is the first rate ratio. This is the second rate ratio.

5. The method according to claim 1, characterized in that, The construction of vibration acceleration evaluation index based on the first vibration acceleration and the second vibration acceleration includes: The minimum value of the first negative acceleration of the first vibration acceleration within a preset time window before shutdown and the minimum value of the second negative acceleration of the first vibration acceleration within the preset time window after shutdown are obtained, and the ratio of the minimum value of the second negative acceleration to the minimum value of the first negative acceleration is calculated to obtain the first acceleration ratio. Obtain the minimum value of the third negative acceleration of the second vibration acceleration within the preset time window before shutdown, and the minimum value of the fourth negative acceleration of the second vibration acceleration within the preset time window after shutdown, and calculate the ratio of the minimum value of the fourth negative acceleration to the minimum value of the third negative acceleration to obtain the second acceleration ratio. The vibration acceleration evaluation index is constructed based on the first acceleration ratio and the second acceleration ratio.

6. The method according to claim 5, characterized in that, The construction of the vibration acceleration evaluation index based on the first acceleration ratio and the second acceleration ratio includes: The vibration acceleration evaluation index is determined by the following formula. : ； in, The acceleration ratio is... This is the second acceleration ratio.

7. The method according to claim 1, characterized in that, Determining whether the installation orientation of the vibration sensor is correct based on the vibration rate evaluation index and the vibration acceleration evaluation index includes: Weighting coefficients are assigned to the vibration rate evaluation index and the vibration acceleration evaluation index respectively, and weighted calculations are performed to obtain the installation direction identification index; The installation orientation of the vibration sensor is determined based on the installation orientation identification index.

8. The method according to claim 7, characterized in that, Determining whether the installation direction of the vibration sensor is correct based on the installation direction identification index includes: If the installation direction identification index is greater than 0, then the installation direction of the vibration sensor is correct; If the installation direction identification index is not greater than 0, then the installation direction of the vibration sensor is incorrect.

9. The method according to any one of claims 1-8, characterized in that, Also includes: When the vibration sensor is installed in the correct orientation: The system acquires the first moment corresponding to the minimum negative velocity during the shutdown process and the second moment corresponding to the maximum positive velocity during the shutdown process, and determines whether the signal polarity of the vibration sensor is correct based on the first moment and the second moment.

10. The method according to claim 9, characterized in that, Determining whether the signal polarity of the vibration sensor is correct based on the first time point and the second time point includes: If the first moment is earlier than the second moment, then the signal polarity of the vibration sensor is correct; If the first moment is not earlier than the second moment, then the signal polarity of the vibration sensor is incorrect.

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