Method, device, equipment and medium for identifying vibration limit exceeded failure of offshore wind turbine

Abstract

To provide a method, device, equipment and medium for identifying a vibration limit exceeded failure of an offshore wind turbine.SOLUTION: A method for identifying a vibration limit exceeded failure of an offshore wind turbine, includes: when a resonance limit exceeded failure occurs in an offshore turbine, executing Fourier spectrum analysis on first vibration acceleration data before the vibration limit exceeded failure occurs, second vibration acceleration data in a vibration limit exceeded failure stage, and third vibration acceleration data in a turbine stop stage; determining an excitation frequency of the turbine in an impeller normal rotation stage, an excitation frequency of the turbine in the vibration limit exceeded failure stage, and a natural frequency in a stop stage; and determining whether the resonance limit exceeded failure occurs in the offshore turbine on the basis of a first deviation value between the excitation frequency and the natural frequency of the turbine in the impeller normal rotation stage, a second deviation value between the excitation frequency and the natural frequency of the turbine in which the vibration limit exceeded failure occurs, and a preset deviation value. This method solves the problems in related techniques such as wasted resources and unnecessary outage due to manual troubleshooting.SELECTED DRAWING: Figure 1

Description

[Technical field]

[0001] The present invention relates to the technical field of electrical signal processing, and in particular to a method, apparatus, device and medium for identifying vibration limit exceeding faults in offshore wind turbines. [Background technology]

[0002] Offshore wind power generation has the advantage that the amount of electricity generated by the turbine is large and it is suitable for development. Currently, offshore wind power generation is experiencing a period of rapid development, but the installation environment for offshore wind power turbines is special, making them prone to various breakdowns due to environmental influences. Therefore, operation, maintenance, and inspection work for offshore wind power generation is extremely important.

[0003] Currently, when an offshore wind turbine detects a failure in the nacelle that exceeds the vibration limit, the turbine is stopped and operation, maintenance, and inspection work is performed by operation and maintenance personnel. When operation and maintenance personnel perform operation and maintenance work, they usually investigate each possible failure that may occur in the offshore wind turbine one by one based on past experience, which has the disadvantage of wasting human resources and taking time. Summary of the Invention [Problem to be solved by the invention]

[0004] In view of the above, the present invention provides a method, apparatus, device, and medium for identifying vibration limit exceeding faults in offshore wind turbines to solve the problems of wasted human resources and time consuming problems present in conventional troubleshooting methods for offshore wind turbines. [Means for solving the problem]

[0005] In a first aspect, the present invention provides a method for producing a composition comprising the steps of: When a vibration limit exceeding fault occurs in the offshore turbine, the method includes the steps of: acquiring first vibration acceleration data within a preset period before the occurrence of a vibration limit exceeding fault in the offshore turbine; second vibration acceleration data in a vibration limit exceeding fault stage; and third vibration acceleration data in a turbine stop stage; and performing Fourier spectrum analysis on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data, wherein the first frequency is a frequency that indicates that the offshore turbine has exceeded the vibration limit. The present invention provides a method for identifying a vibration limit exceeding fault of an offshore wind turbine, comprising the steps of: determining a first deviation value between the first frequency and the third frequency and a second deviation value between the second frequency and the third frequency; determining whether a resonance limit exceeding fault has occurred in the offshore turbine based on the first deviation value, the second deviation value, and a preset deviation value, and obtaining a fault identification result.

[0006] In the method for identifying a vibration limit exceeding fault of an offshore wind power turbine according to the present invention, when a resonance limit exceeding fault occurs in the offshore turbine, a Fourier spectrum analysis is performed on first vibration acceleration data within a preset period before the occurrence of a vibration limit exceeding fault in the offshore turbine, second vibration acceleration data in the vibration limit exceeding fault stage, and third vibration acceleration data in the turbine stop stage to obtain an excitation frequency of the turbine in an impeller normal rotation stage before the occurrence of a vibration limit exceeding fault in the offshore turbine, an excitation frequency of the turbine when a vibration limit exceeding fault occurs in the offshore turbine, and a natural frequency of the offshore turbine stop stage. Whether or not a resonance limit exceeding fault has occurred in the offshore turbine is determined based on a first deviation value between the excitation frequency and the natural frequency of the turbine in the impeller normal rotation stage, a second deviation value between the excitation frequency and the natural frequency of the turbine in which a vibration limit exceeding fault has occurred, and the preset deviation value, thereby realizing intelligent diagnosis of the vibration fault of the offshore turbine, and the cause of the vibration limit exceeding fault of the offshore turbine can be identified by analyzing the vibration acceleration data of the offshore turbine, thereby solving the problems in the related art of wasting human resources and taking time caused by manual troubleshooting.

[0007] In a preferred embodiment, after the step of determining whether a resonance limit exceeding fault has occurred in the offshore turbine based on the first deviation value, the second deviation value, and the preset deviation value and obtaining a fault identification result, the method further includes the step of determining a fault handling recipe based on the fault identification result.

[0008] In the method according to the preferred embodiment, a fault handling recipe is determined based on the fault identification results, thereby improving the efficiency of operation, maintenance and inspection work of offshore wind power generation and ensuring the safe operation of the turbine.

[0009] In a preferred embodiment, after the step of determining whether a resonance limit exceeding fault has occurred in the offshore turbine based on the first deviation value, the second deviation value, and the predetermined deviation value and obtaining a fault identification result, the method further includes the steps of: if a resonance limit exceeding fault has occurred in the offshore turbine, determining a sweep frequency band of the blades of the offshore turbine based on a rotation speed range of the impeller of the offshore turbine; determining whether a third frequency is within the sweep frequency band; if the third frequency is within the sweep frequency band, determining a resonant speed range corresponding to the sweep frequency band based on the third frequency; and determining whether a self-excited resonant fault has occurred in the offshore turbine based on the resonant speed range and the actual measured rotation speed of the impeller before the vibration limit exceeding fault occurred in the offshore turbine.

[0010] In the method according to this preferred embodiment, it is advantageous to determine whether a self-excited resonant fault has occurred in the offshore turbine based on the swept frequency band and natural frequency of the offshore turbine, and then determine a corresponding fault solution based on the determination result.

[0011] In a possible embodiment, when a vibration limit exceeding failure occurs in the offshore turbine, before the step of acquiring first vibration acceleration data within a target period before a vibration limit exceeding failure occurs in the offshore turbine, second vibration acceleration data in the vibration limit exceeding failure stage and third vibration acceleration data in the turbine stop stage, the method further includes a step of acquiring vibration acceleration data in a nacelle of the offshore turbine, a step of comparing the vibration acceleration data with each of predetermined threshold values ​​to obtain a comparison result, and a step of determining whether a vibration limit exceeding failure has occurred in the offshore turbine based on the comparison result.

[0012] In the method according to the preferred embodiment, the vibration acceleration data is compared with a preset threshold value, and based on the comparison result, it can be accurately determined whether a vibration limit exceeding fault has occurred in the offshore turbine.

[0013] In a preferred embodiment, when a vibration limit exceeding failure occurs in the offshore turbine, before the step of acquiring first vibration acceleration data within a target period before the occurrence of a vibration limit exceeding failure in the offshore turbine, second vibration acceleration data in the vibration limit exceeding failure phase and third vibration acceleration data in the turbine stop phase, the method further includes the steps of acquiring vibration acceleration data collected by the first acceleration sensor and vibration acceleration data collected by the second acceleration sensor, determining whether or not the operating states of the first acceleration sensor and the second acceleration sensor are normal based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor, if the operating states of the first acceleration sensor and the second acceleration sensor are normal, determining whether or not a vibration limit exceeding failure has occurred in the offshore turbine based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor, and sending a stop control command to the offshore turbine when it is determined that a vibration limit exceeding failure has occurred in the offshore turbine.

[0014] In the method according to the preferred embodiment, it is possible to more accurately determine whether a resonance limit exceeding fault occurs in an offshore turbine, and effectively solve the problem of turbine shutdown due to the abnormal working state of the vibration sensor.

[0015] In a possible embodiment, the step of determining whether a vibration limit exceeding fault has occurred in the offshore turbine based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor includes a step of comparing the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor with predetermined thresholds, respectively, to obtain a comparison result, and a step of determining that a vibration limit exceeding fault has occurred in the offshore turbine if the vibration acceleration data collected by the first acceleration sensor is greater than the predetermined threshold and / or if the vibration acceleration data collected by the second acceleration sensor is greater than the predetermined threshold.

[0016] The method according to the preferred embodiment more accurately determines whether an offshore turbine has experienced a resonance limit exceeding fault.

[0017] In a possible embodiment, when a vibration limit exceeding failure occurs on the offshore turbine, the step of acquiring first vibration acceleration data within a predetermined period before a vibration limit exceeding failure occurs on the offshore turbine, second vibration acceleration data in the vibration limit exceeding failure stage, and third vibration acceleration data in the turbine stop stage includes the step of acquiring first initial vibration acceleration data, second initial vibration acceleration data in the vibration limit exceeding failure stage, and third initial vibration acceleration data in the turbine stop stage within a predetermined period before a vibration limit exceeding failure occurs on the offshore turbine, when a vibration limit exceeding failure occurs on the offshore turbine, and performing signal zero padding processing on each of the first initial vibration acceleration data, the second initial vibration acceleration data, and the third initial vibration acceleration data to obtain first vibration acceleration data corresponding to the first initial vibration acceleration data, second vibration acceleration data corresponding to the second initial vibration acceleration data, and third vibration acceleration data corresponding to the third initial vibration acceleration data.

[0018] In the method according to the present embodiment, it becomes easy to obtain highly accurate spectrum analysis results by increasing the vibration acceleration data, shortening the frequency analysis interval, and later performing Fourier spectrum analysis on the vibration acceleration data.

[0019] In a second aspect, the present invention provides a first acquisition module for acquiring, when a vibration limit exceeding fault occurs in an offshore turbine, first vibration acceleration data within a preset period before the occurrence of a vibration limit exceeding fault in the offshore turbine, second vibration acceleration data in a vibration limit exceeding fault stage, and third vibration acceleration data in a turbine stop stage; and a spectrum analysis module for performing Fourier spectrum analysis on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data, wherein the first frequency is a frequency that is proportional to the vibration limit of the offshore turbine. Provided is a device for identifying a vibration limit exceeding fault in an offshore wind power turbine, the device including: a spectrum analysis module, in which a first frequency is the excitation frequency of the turbine in an impeller normal rotation phase before a vibration limit exceeding fault occurs, a second frequency is the excitation frequency of the turbine when a vibration limit exceeding fault occurs in the offshore turbine, and a third frequency is a natural frequency of an offshore turbine stop phase; a first determination module, which determines a first deviation value between the first frequency and the third frequency and a second deviation value between the second frequency and the third frequency; and a second determination module, which determines whether a resonance limit exceeding fault has occurred in the offshore turbine based on the first deviation value, the second deviation value, and a predetermined deviation value, and obtains a fault identification result.

[0020] In a possible embodiment, the apparatus further includes a third determination module for determining a fault treatment recipe based on the fault identification result.

[0021] In a third aspect, the present invention provides a computing device comprising: a memory; and a processor, the memory and the processor being communicatively coupled to each other, the memory having computer instructions stored therein, the processor executing the computer instructions to perform the method for identifying vibration limit exceeding faults in an offshore wind turbine as defined in any one of the first aspect above or corresponding embodiments thereof.

[0022] In a fourth aspect, the present invention provides a computer readable storage medium having stored thereon computer instructions for causing a computer to perform a method for identifying vibration limit exceeding faults in an offshore wind turbine as described in any one of the first aspect or corresponding embodiments above. [Brief description of the drawings]

[0023] In order to more clearly describe the specific embodiments of the present invention or the technical solutions in the prior art, the following will briefly introduce the drawings required for the description of the specific embodiments or the prior art. It is obvious that the drawings in the following description are some embodiments of the present invention, and those skilled in the art can obtain other drawings based on these drawings without any creative efforts. [Figure 1] 1 is a flow diagram of a method for identifying vibration limit exceeding faults in an offshore wind turbine according to an embodiment of the present invention; [Figure 2A] FIG. 11 is a schematic diagram showing information on a change over time in the Y-direction vibration acceleration of the first vibration acceleration in the embodiment of the present invention. [Figure 2B] FIG. 11 is a schematic diagram showing a Fourier spectrum analysis result of the vibration acceleration in the Y direction of the first vibration acceleration in the embodiment of the present invention. [Figure 2C] FIG. 13 is a schematic diagram showing information on a change over time in the Y-direction vibration acceleration of the second vibration acceleration in the embodiment of the present invention. [Figure 2D] FIG. 11 is a schematic diagram showing a Fourier spectrum analysis result of the vibration acceleration in the Y direction among the second vibration accelerations in the embodiment of the present invention. [Figure 2E] FIG. 13 is a schematic diagram showing information on a change over time in the Y-direction vibration acceleration of the third vibration acceleration in the embodiment of the present invention. [Figure 2F] FIG. 11 is a schematic diagram showing a Fourier spectrum analysis result of the vibration acceleration in the Y direction among the third vibration accelerations in the embodiment of the present invention. [Figure 2G] FIG. 11 is a schematic diagram showing information on a change over time in the vibration acceleration in the X direction among the first vibration accelerations according to the embodiment of the present invention. [Figure 2H]FIG. 11 is a schematic diagram showing a Fourier spectrum analysis result of the vibration acceleration in the X direction of the first vibration acceleration in the embodiment of the present invention. [Figure 2I] FIG. 13 is a schematic diagram showing information on a change over time in the vibration acceleration in the X direction among the second vibration accelerations in the embodiment of the present invention. [Figure 2J] FIG. 11 is a schematic diagram showing a Fourier spectrum analysis result of the vibration acceleration in the X direction among the second vibration accelerations in the embodiment of the present invention. [Figure 2K] FIG. 13 is a schematic diagram showing information on a change over time in the X-direction vibration acceleration of the third vibration acceleration in the embodiment of the present invention. [Figure 2L] FIG. 11 is a schematic diagram showing a Fourier spectrum analysis result of the vibration acceleration in the X direction among the third vibration accelerations in the embodiment of the present invention. [Diagram 3] 4 is a flow diagram of a method for identifying vibration limit exceeding faults in another offshore wind turbine according to an embodiment of the present invention. [Figure 4] 4 is a flow diagram of a method for identifying vibration limit exceeding faults in a further offshore wind turbine according to an embodiment of the present invention. [Diagram 5] 4 is a flow diagram of a method for identifying vibration limit exceeding faults in a further offshore wind turbine according to an embodiment of the present invention. [Figure 6] 4 is a flow diagram of a method for identifying vibration limit exceeding faults in a further offshore wind turbine according to an embodiment of the present invention. [Figure 7] 4 is a flow diagram of a method for identifying vibration limit exceeding faults in a further offshore wind turbine according to an embodiment of the present invention. [Figure 8] FIG. 2 is a structural block diagram of an apparatus for identifying vibration limit exceeding faults of an offshore wind turbine according to an embodiment of the present invention; [Figure 9] FIG. 2 is a schematic diagram illustrating a hardware configuration of a computer device according to an embodiment of the present invention. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

[0024] In order to make the objectives, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be described clearly and completely below with reference to the drawings in the embodiments of the present invention, but it is clear that the described embodiments are only a part of the embodiments of the present invention, and are not all of the embodiments. All other embodiments obtained by those skilled in the art based on the embodiments of the present invention without any creative efforts belong to the protection scope of the present invention.

[0025] In response to the disadvantages of the related art in that possible faults that may occur in offshore wind turbines are investigated one by one based on past experience, which wastes human resources and takes time, an embodiment of the present invention proposes a method for identifying vibration limit exceeding faults in offshore wind turbines that can be applied to any electronic device or processor, and determines the fault identification result of the offshore turbine by processing and analyzing vibration acceleration data of the offshore turbine.

[0026] According to an embodiment of the present invention, an embodiment of a method for identifying vibration limit exceeding faults in an offshore wind turbine is provided. It is noted that the steps illustrated in the flow charts in the figures may be performed in a computer system, such as in computer-executable instructions, and that although a logical order is shown in the flow charts, in some cases the steps shown or described may be performed in a different order than shown.

[0027] In this embodiment, a method for identifying a vibration limit exceeding fault of an offshore wind turbine is provided, which can be applied to the above-mentioned electronic device and processor, etc. Fig. 1 is a flow chart of a method for identifying a vibration limit exceeding fault of an offshore wind turbine according to an embodiment of the present invention, and as shown in Fig. 1, the flow includes the following steps S101 to S104.

[0028] Step S101: When a vibration limit exceeding fault occurs in an offshore turbine, first vibration acceleration data within a preset period before the vibration limit exceeding fault occurs in the offshore turbine, second vibration acceleration data during the vibration limit exceeding fault stage, and third vibration acceleration data during the turbine stop stage are obtained.

[0029] For example, the occurrence of a vibration limit exceeding fault in an offshore turbine refers to determining that a vibration limit exceeding fault has occurred in the offshore turbine when the vibration of the offshore turbine exceeds a preset management threshold. The first vibration acceleration, the second vibration acceleration, and the third vibration acceleration are collected by a vibration acceleration sensor preset in the turbine, and the vibration acceleration sensor collects vibration acceleration data of the offshore turbine in real time based on preset sampling, and the first vibration acceleration data may be data within a preset period before the vibration limit exceeding fault occurs, and the preset period may be any period, and the preset period is not particularly limited in the embodiments of the present application and may be determined as necessary by those skilled in the art, and in the embodiments of the present application, the preset period may include, but is not limited to, one minute.

[0030] Step S102: Perform Fourier spectrum analysis on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data. The first frequency is an excitation frequency of the turbine in a normal impeller rotation stage before a vibration limit exceeding fault occurs in the offshore turbine, the second frequency is an excitation frequency of the turbine when a vibration limit exceeding fault occurs in the offshore turbine, and the third frequency is a natural frequency of the offshore turbine in a stopped stage.

[0031] Illustratively, in the embodiment of the present application, the Fourier spectrum analysis refers to dividing and analyzing the vibration signal in the time domain, and acquiring the frequency at which the power spectrum density is maximum as the main frequency within that period. The vibration acceleration sensor may collect vibration acceleration data in two directions, X (parallel to the wind surface of the blade) and Y (perpendicular to the wind surface of the blade) in the nacelle of the turbine, and information on the change over time of the vibration acceleration in the Y direction of the first vibration acceleration is shown in FIG. 2A, and the result of performing Fourier spectrum analysis on the vibration acceleration data in the Y direction of the first vibration acceleration is shown in FIG. 2B. As can be seen from FIG. 2A and FIG. 2B, the time domain data of the vibration acceleration of the nacelle in the Y direction in the time range of -60s to -20s is converted into a curve of the relationship between the autospectral density amplitude and frequency by Fourier transform, and the energy (amplitude) is 0.53 at maximum, and the vibration frequency corresponding to the maximum energy is 0.275Hz, which is based on the vibration excitation frequency in the Y direction during the normal operation phase of the turbine. Information on the change over time of the vibration acceleration in the Y direction among the second vibration acceleration is shown in FIG. 2C, and the result of performing Fourier spectrum analysis on the second vibration acceleration is shown in FIG. 2D. As can be seen from FIG. 2C and FIG. 2D, the time domain data of the vibration acceleration of the nacelle in the Y direction in the time range of -10s to 10s is converted into a curve of the relationship between the frequency domain amplitude and frequency by Fourier transform, and the energy (amplitude) is a maximum of 0.313, and the vibration frequency corresponding to the maximum energy is 0.35Hz, which is based on the vibration frequency in the Y direction at the stage of exceeding the vibration limit of the turbine. Information on the change over time of the vibration acceleration in the Y direction among the third vibration acceleration is shown in FIG. 2E, and the result of performing Fourier spectrum analysis on the third vibration acceleration is shown in FIG. 2F. As can be seen from Figures 2E and 2F, in the time range of 20 s to 60 s, the time domain data of the vibration acceleration of the nacelle in the Y direction was Fourier transformed, and the maximum energy was 0.144, and the vibration frequency corresponding to the maximum energy was 0.325 Hz, which is based on the vibration frequency in the Y direction during the turbine stopping phase and is close to the overall natural frequency, i.e., the natural frequency.Information on the change over time of the vibration acceleration in the X direction among the first vibration acceleration is shown in FIG. 2G, and the result of performing Fourier spectrum analysis on the first vibration acceleration is shown in FIG. 2H. As can be seen from FIG. 2G and FIG. 2H, the time domain data of the vibration acceleration of the nacelle in the X direction in the time range of -60s to -20s is converted into frequency domain amplitude by Fourier transform, and the maximum energy is 0.069, and the vibration frequency corresponding to the maximum energy is 0.325Hz, which is based on the vibration excitation frequency in the X direction in the normal operation phase of the turbine. Information on the change over time of the vibration acceleration in the X direction among the second vibration acceleration is shown in FIG. 2I, and the result of performing Fourier spectrum analysis on the second vibration acceleration is shown in FIG. 2J. As can be seen from FIG. 2I and FIG. 2J, in the time range of -10s to 10s, the time domain data of the vibration acceleration of the nacelle in the X direction was transformed into a curve of the relationship between the frequency domain amplitude and frequency by Fourier transformation, and the maximum energy was 0.187, and the vibration frequency corresponding to the maximum energy was 0.35Hz, which is based on the vibration frequency in the X direction of the turbine vibration limit exceeding stage. The information of the change over time of the vibration acceleration in the X direction of the third vibration acceleration is shown in FIG. 2K, and the result of Fourier spectrum analysis on the third vibration acceleration is shown in FIG. 2L. As can be seen from FIG. 2K and FIG. 2L, in the time range of 20s to 60s, the time domain data of the vibration acceleration of the nacelle in the X direction was transformed into a curve of the frequency domain amplitude and frequency, which is close to the natural frequency of the whole, i.e., the natural frequency. The frequency data of each stage obtained above is shown in Table 1 below.

[0032] JPEG2025015445000002.jpg28170

[0033] Step S103: Determine a first deviation value between the first frequency and the third frequency, and a second deviation value between the second frequency and the third frequency.

[0034] For example, the first deviation value refers to a difference value between the first frequency and the third frequency, and the second deviation value refers to a deviation value between the second frequency and the third frequency. In the embodiment of the present application, the data Y in Table 1 is analyzed, and it is found that the vibration response frequency of the vibration acceleration of the nacelle during the operation of the turbine is about 0.275Hz and 0.35Hz, and the vibration frequency after the turbine is stopped is 0.325Hz, the first deviation value is a value obtained by subtracting 0.325Hz from 0.275Hz, and the second deviation value is a value obtained by subtracting 0.325Hz from 0.35Hz.

[0035] Step S104: Determine whether a resonance limit exceeding fault occurs in the offshore turbine according to the first deviation value, the second deviation value, and the preset deviation value, and obtain a fault identification result.

[0036] For example, the preset deviation value may be any value, and in the embodiment of the present application, the preset deviation value is not particularly limited and may be determined as necessary by a person skilled in the art. In the embodiment of the present application, the preset deviation value may include, but is not limited to, 0.05, and when the first deviation value or the second deviation value is less than 0.05, it is determined that a resonance limit exceeding fault has occurred in the offshore turbine.

[0037] In the method for identifying a vibration limit exceeding fault of an offshore wind power turbine according to the present embodiment, when a resonance limit exceeding fault occurs in an offshore turbine, a Fourier spectrum analysis is performed on first vibration acceleration data within a preset period before the occurrence of a vibration limit exceeding fault in the offshore turbine, second vibration acceleration data in the vibration limit exceeding fault stage, and third vibration acceleration data in the turbine stop stage to obtain an excitation frequency of the turbine in an impeller normal rotation stage before the occurrence of a vibration limit exceeding fault in the offshore turbine, an excitation frequency of the turbine when a vibration limit exceeding fault occurs in the offshore turbine, and a natural frequency of the offshore turbine stop stage. Then, based on a first deviation value between the excitation frequency and the natural frequency of the turbine in the impeller normal rotation stage, a second deviation value between the excitation frequency and the natural frequency of the turbine in which a vibration limit exceeding fault has occurred, and the preset deviation value, it is determined whether a resonance limit exceeding fault has occurred in the offshore turbine, thereby realizing intelligent diagnosis of the vibration fault of the offshore turbine, and the cause of the vibration limit exceeding fault of the offshore turbine can be identified by analyzing the vibration acceleration data of the offshore turbine, thereby solving the problems in the related art of wasting human resources and taking time caused by manual troubleshooting.

[0038] In this embodiment, a method for identifying a vibration limit exceeding fault of an offshore wind turbine is provided, which can be applied to the above-mentioned electronic device and processor, etc. Fig. 3 is a flow chart of a method for identifying a vibration limit exceeding fault of an offshore wind turbine according to an embodiment of the present invention, and as shown in Fig. 3, this flow includes the following steps S301 to S305.

[0039] Step S301: When a vibration limit exceeding fault occurs in an offshore turbine, first vibration acceleration data within a preset period before the vibration limit exceeding fault occurs in the offshore turbine, second vibration acceleration data in the vibration limit exceeding fault stage, and third vibration acceleration data in the turbine stop stage are obtained. For details, refer to step S101 in the embodiment shown in FIG. 1, and therefore will not be described in detail here.

[0040] Step S302: Fourier spectrum analysis is performed on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data. The first frequency is the excitation frequency of the turbine in the impeller normal rotation stage before the occurrence of a vibration limit exceeding fault in the offshore turbine, the second frequency is the excitation frequency of the turbine when the vibration limit exceeding fault occurs in the offshore turbine, and the third frequency is the natural frequency of the offshore turbine stop stage. Details can be referred to step S102 in the embodiment shown in FIG. 1, so they will not be described in detail here.

[0041] Step S303: Determine a first deviation value between the first frequency and the third frequency, and a second deviation value between the second frequency and the third frequency. For details, refer to step S103 in the embodiment shown in FIG. 1, and will not be described in detail here.

[0042] Step S304: Determine whether a resonance limit exceeding fault occurs in the offshore turbine based on the first deviation value, the second deviation value, and the preset deviation value, and obtain a fault identification result. For details, refer to step S104 in the embodiment shown in FIG. 1, and thus will not be described in detail here.

[0043] After the above step S304, the method specifically further includes step S305.

[0044] Step S305: Based on the fault identification result, a fault treatment recipe is determined.

[0045] For example, the enemy's fault handling recipe is determined based on the fault identification result. For example, when the turbine has a resonance limit exceeding fault, a corresponding solution can be provided according to the resonance limit exceeding fault. When a non-resonance fault occurs, first determine whether the turbine vibration limit exceeding is due to the wind load such as a typhoon, and if the typhoon factor is excluded, determine that it is due to the imbalance of the force received during the rotation of the turbine. The cause is generally a mechanical problem occurring inside the wind turbine, which causes the balance of the force received by the structure during the rotation of the turbine impeller, such as the loss of synchronization of the individual pitch system, the misalignment of the installation position of the standard zero baseline of the three blades, wear on the friction contact surface of the main bearing inside the gearbox, insufficient lubrication of the bearing, incorrect lubrication method, unbalanced rotor mass, loose connection member of the impeller, etc., which causes the vibration limit exceeding fault. Check the possible faults one by one to identify the cause of the fault.

[0046] In a method for identifying vibration limit exceeding faults in an offshore wind power turbine according to an embodiment of the present invention, a fault handling recipe is determined based on the fault identification results, thereby improving the efficiency of operation, maintenance, and inspection work for offshore wind power generation and ensuring safe operation of the turbine.

[0047] In this embodiment, a method for identifying a vibration limit exceeding fault of an offshore wind turbine is provided, which can be applied to the above-mentioned electronic device and processor, etc. Fig. 4 is a flow chart of a method for identifying a vibration limit exceeding fault of an offshore wind turbine according to an embodiment of the present invention, and as shown in Fig. 4, this flow includes the following steps S401 to S408.

[0048] Step S401: When a vibration limit exceeding fault occurs in an offshore turbine, first vibration acceleration data within a preset period before the vibration limit exceeding fault occurs in the offshore turbine, second vibration acceleration data in a vibration limit exceeding fault stage, and third vibration acceleration data in a turbine stop stage are obtained. For details, refer to step S101 in the embodiment shown in FIG. 1, and therefore will not be described in detail here.

[0049] Step S402: Fourier spectrum analysis is performed on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data. The first frequency is the excitation frequency of the turbine in the impeller normal rotation stage before the occurrence of a vibration limit exceeding fault in the offshore turbine, the second frequency is the excitation frequency of the turbine when the vibration limit exceeding fault occurs in the offshore turbine, and the third frequency is the natural frequency of the offshore turbine stop stage. Details can be referred to step S102 in the embodiment shown in FIG. 1, so they will not be described in detail here.

[0050] Step S403: Determine a first deviation value between the first frequency and the third frequency, and a second deviation value between the second frequency and the third frequency. For details, refer to step S103 in the embodiment shown in FIG. 1, and will not be described in detail here.

[0051] Step S404: Determine whether a resonance limit exceeding fault occurs in the offshore turbine based on the first deviation value, the second deviation value, and the preset deviation value, and obtain a fault identification result. For details, refer to step S104 in the embodiment shown in FIG. 1, and thus will not be described in detail here.

[0052] Specifically, after the above step S404, the method further includes steps S405 to S408.

[0053] Step S405: When a resonance limit exceeding fault occurs in the offshore turbine, a sweep frequency band of the blades of the offshore turbine is determined based on the rotation speed range of the impeller of the offshore turbine.

[0054] Exemplarily, the impeller speed range is a parameter set for the turbine at the time of shipment, and the sweep frequency band may include, but is not limited to, a 1P frequency band and a 3P frequency band, and the 1P frequency band and the 3P frequency band may be determined based on the impeller speed range, for example, if the RMP range of the impeller speed range is RPM1-RPM2, and the 1P frequency band is the frequency at which the turbine hub rotates once, then the 1P frequency band f1p=RPM1 / 60-RPM2 / 60, and the 3P frequency band is the frequency at which three blades pass through the tower shadow, in this case the 3P frequency band f3p=(RPM1 / 60-RPM2 / 60)*3. In the embodiment of the present application, the sweep frequency band may be the 3P frequency band.

[0055] Step S406: Determine whether the third frequency is within the sweep frequency band. Illustratively, in the embodiment of the present application, determine whether the third frequency is within the 3P frequency band according to the value of the third frequency and the range of the 3P frequency band.

[0056] Step S407: If the third frequency is within the sweep frequency band, determine a resonant rotation speed interval corresponding to the sweep frequency band based on the third frequency.

[0057] For example, in an embodiment of the present application, if the third frequency is outside the 3P frequency band, it is determined that vortex-induced resonance has occurred in the offshore turbine, and if the third frequency is within the 3P frequency band, the 3P resonant speed range is calculated based on the third frequency, and the 3P resonant speed R3P = fs * 60s / 3, where fs is the third resonant frequency, s is the time unit (seconds), and the 3P resonant speed range is ±15% of R3P.

[0058] Step S408: Determine whether a self-excited resonance fault has occurred in the offshore turbine based on the resonance speed interval and the measured impeller speed before the occurrence of a vibration limit exceeding fault in the offshore turbine. For example, if the measured impeller speed before the occurrence of a vibration limit exceeding fault in the offshore turbine is within the resonance speed interval, it is determined that a self-excited resonance fault has occurred in the offshore turbine, and otherwise, it is determined that a vortex-induced resonance fault has occurred in the offshore turbine.

[0059] In the method for identifying vibration limit exceeding faults of an offshore wind turbine according to an embodiment of the present invention, it is advantageous to determine whether a self-excited resonant fault occurs in the offshore turbine based on the swept frequency band and natural frequency of the offshore turbine, and determine a corresponding fault solution based on the judgment result.

[0060] In this embodiment, a method for identifying a vibration limit exceeding fault of an offshore wind turbine is provided, which can be applied to the above-mentioned electronic device and processor, etc. Fig. 5 is a flow chart of a method for identifying a vibration limit exceeding fault of an offshore wind turbine according to an embodiment of the present invention, and as shown in Fig. 5, this flow includes the following steps S501 to S507.

[0061] Step S501: Obtain vibration acceleration data in a nacelle of an offshore turbine. Exemplarily, the vibration acceleration data in a nacelle of an offshore turbine is collected by a vibration acceleration sensor installed in the nacelle.

[0062] Step S502: The vibration acceleration data is compared with a preset threshold value, and a comparison result is obtained. Illustratively, the preset threshold value may be a preset management threshold value, and in the embodiment of the present application, the preset threshold value is not particularly limited and may be determined as necessary by a person skilled in the art.

[0063] Step S503: Based on the comparison result, it is determined whether a vibration limit exceeding fault occurs in the offshore turbine. For example, if the vibration acceleration is greater than a preset threshold, it is determined that a vibration limit exceeding fault occurs in the offshore turbine.

[0064] Step S504: When a vibration limit exceeding fault occurs in the offshore turbine, first vibration acceleration data within a preset period before the vibration limit exceeding fault occurs in the offshore turbine, second vibration acceleration data in the vibration limit exceeding fault stage, and third vibration acceleration data in the turbine stop stage are obtained. For details, refer to step S101 in the embodiment shown in FIG. 1, and therefore will not be described in detail here.

[0065] Step S505: Fourier spectrum analysis is performed on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data. The first frequency is the excitation frequency of the turbine in the impeller normal rotation stage before the occurrence of a vibration limit exceeding fault in the offshore turbine, the second frequency is the excitation frequency of the turbine when the vibration limit exceeding fault occurs in the offshore turbine, and the third frequency is the natural frequency of the offshore turbine stop stage. Details can be referred to step S102 in the embodiment shown in FIG. 1, so they will not be described in detail here.

[0066] Step S506: Determine a first deviation value between the first frequency and the third frequency, and a second deviation value between the second frequency and the third frequency. For details, refer to step S103 in the embodiment shown in FIG. 1, and will not be described in detail here.

[0067] Step S507: Determine whether a resonance limit exceeding fault occurs in the offshore turbine based on the first deviation value, the second deviation value, and the preset deviation value, and obtain a fault identification result. For details, refer to step S104 in the embodiment shown in FIG. 1, and thus will not be described in detail here.

[0068] In an embodiment of the present invention, a method for identifying a vibration limit exceeding fault of an offshore wind turbine is provided, which compares vibration acceleration data with a preset threshold value, and based on the comparison result, can accurately determine whether a vibration limit exceeding fault has occurred in the offshore turbine.

[0069] In this embodiment, a method for identifying a vibration limit exceeding fault of an offshore wind turbine is provided, which can be applied to the above-mentioned electronic device and processor, etc. Fig. 6 is a flow chart of a method for identifying a vibration limit exceeding fault of an offshore wind turbine according to an embodiment of the present invention, and as shown in Fig. 6, this flow includes the following steps S601 to S608.

[0070] Step S601: Obtain vibration acceleration data collected by the first acceleration sensor and vibration acceleration data collected by the second acceleration sensor. Exemplarily, in an embodiment of the present application, two vibration acceleration sensors, the first acceleration sensor and the second acceleration sensor, can be arranged symmetrically along the center line of the main shaft in a nacelle of an offshore turbine.

[0071] Step S602: Based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor, it is determined whether the operation state of the first acceleration sensor and the second acceleration sensor is normal. For example, based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor, it is determined whether a jump abnormality occurs in the acceleration data. Specifically, if there is a sudden change in the amplitude of a total of four sets of data in the X direction and the Y direction by the two acceleration sensors installed in the turbine nacelle, it indicates that a failure has occurred in the sensor, and if the amplitudes of a total of four sets of data in the X direction and the Y direction by the two acceleration sensors installed in the turbine nacelle are close, it indicates that the operation state of the sensor is reliable and no jump abnormality occurs in the data.

[0072] Step S603: If the operating conditions of the first acceleration sensor and the second acceleration sensor are normal, determine whether or not a vibration limit exceeding fault has occurred in the offshore turbine based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor. Exemplarily, if the operating conditions of the first acceleration sensor and the second acceleration sensor are normal as a result of the monitoring, further determine whether or not a vibration limit exceeding fault has occurred in the offshore turbine based on the vibration acceleration data collected by the acceleration sensors.

[0073] Step S604: When it is determined that a vibration limit exceeding fault has occurred in the offshore turbine, a stop control command is sent to the offshore turbine. For example, when a vibration limit exceeding fault has occurred in the offshore turbine, the offshore turbine is controlled to stop.

[0074] Step S605: When a vibration limit exceeding fault occurs in the offshore turbine, first vibration acceleration data within a preset period before the vibration limit exceeding fault occurs in the offshore turbine, second vibration acceleration data in the vibration limit exceeding fault stage, and third vibration acceleration data in the turbine stop stage are obtained. For details, refer to step S101 in the embodiment shown in FIG. 1, and therefore will not be described in detail here.

[0075] Step S606: Fourier spectrum analysis is performed on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data. The first frequency is the excitation frequency of the turbine in the impeller normal rotation stage before the occurrence of a vibration limit exceeding fault in the offshore turbine, the second frequency is the excitation frequency of the turbine when the vibration limit exceeding fault occurs in the offshore turbine, and the third frequency is the natural frequency of the offshore turbine stop stage. Details can be referred to step S102 of the embodiment shown in FIG. 1, so they will not be described in detail here.

[0076] Step S607: Determine a first deviation value between the first frequency and the third frequency, and a second deviation value between the second frequency and the third frequency. For details, refer to step S103 in the embodiment shown in FIG. 1, and will not be described in detail here.

[0077] Step S608: Determine whether a resonance limit exceeding fault occurs in the offshore turbine based on the first deviation value, the second deviation value, and the preset deviation value, and obtain a fault identification result. For details, refer to step S104 in the embodiment shown in FIG. 1, and thus will not be described in detail here.

[0078] The method for identifying vibration limit exceeding faults in offshore wind turbines according to an embodiment of the present invention can more accurately determine whether a resonance limit exceeding fault has occurred in the offshore turbine, and effectively solve the problem of turbine shutdown due to the abnormal operating state of the vibration sensor.

[0079] In this embodiment, a method for identifying a vibration limit exceeding fault of an offshore wind turbine is provided, which can be applied to the above-mentioned electronic device and processor, etc. Fig. 7 is a flow chart of a method for identifying a vibration limit exceeding fault of an offshore wind turbine according to an embodiment of the present invention, and as shown in Fig. 7, this flow includes the following steps S701 to S708.

[0080] Step S701: Obtain vibration acceleration data collected by the first acceleration sensor and vibration acceleration data collected by the second acceleration sensor. For details, refer to step S601 in the embodiment shown in FIG. 1, so a detailed description will not be given here.

[0081] Step S702: Determine whether the operating states of the first acceleration sensor and the second acceleration sensor are normal based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor. For example, the details can be referred to step S602 in the embodiment shown in FIG. 1, so they will not be described in detail here.

[0082] Step S703: If the operating status of the first acceleration sensor and the second acceleration sensor is normal, determine whether a vibration limit exceeding fault occurs in the offshore turbine based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor. For details, refer to step S603 in the embodiment shown in FIG. 1, and will not be described in detail here.

[0083] In some preferred embodiments, the above step S703 includes steps S7031 and S7032.

[0084] Step S7031: Compare the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor with a preset threshold value, respectively, to obtain a comparison result. Illustratively, the preset threshold value may be a management threshold value of vibration acceleration determined according to actual needs.

[0085] Step S7032: If the vibration acceleration data collected by the first acceleration sensor is greater than a preset threshold and / or if the vibration acceleration data collected by the second acceleration sensor is greater than a preset threshold, it is determined that a vibration limit exceeding fault has occurred in the offshore turbine. Exemplarily, if the comparison result of the vibration acceleration collected by at least one vibration acceleration sensor is greater than a preset threshold, a vibration limit exceeding fault has occurred in the offshore turbine.

[0086] Step S704: If it is determined that a vibration limit exceeding fault has occurred in the offshore turbine, a shutdown control command is sent to the offshore turbine. For details, refer to step S504 in the embodiment shown in FIG. 1, and therefore, detailed description will not be given here.

[0087] Step S705: When a vibration limit exceeding fault occurs in the offshore turbine, first vibration acceleration data within a preset period before the vibration limit exceeding fault occurs in the offshore turbine, second vibration acceleration data in the vibration limit exceeding fault stage, and third vibration acceleration data in the turbine stop stage are obtained. For details, refer to step S101 in the embodiment shown in FIG. 1, and therefore will not be described in detail here.

[0088] In some preferred embodiments, step S705 includes steps S7051 and S7052.

[0089] Step S7051: When a vibration limit exceeding failure occurs in an offshore turbine, first initial vibration acceleration data within a preset period before the vibration limit exceeding failure occurs in the offshore turbine, second initial vibration acceleration data during the vibration limit exceeding failure stage, and third initial vibration acceleration data during the turbine stop stage are obtained.

[0090] Exemplarily, in an embodiment of the present application, the first initial vibration acceleration data, the second initial vibration acceleration data, and the third initial vibration acceleration data may be original data collected by a vibration acceleration sensor.

[0091] Step S7052: Signal zero padding processing is performed on each of the first initial vibration acceleration data, the second initial vibration acceleration data, and the third initial vibration acceleration data to obtain first vibration acceleration data corresponding to the first initial vibration acceleration data, second vibration acceleration data corresponding to the second initial vibration acceleration data, and third vibration acceleration data corresponding to the third initial vibration acceleration data.

[0092] For example, when performing Fourier FFT spectrum analysis, the length of data collected on-site is limited, and the frequency resolution often does not meet the requirements, where FFT frequency resolution=sampling frequency / FFT length. In order to improve the accuracy of spectrum analysis, a vibration signal zero padding method is used to add a vibration signal with zero amplitude for a certain period of time to the vibration signal, which can effectively extend the FFT length, shorten the frequency analysis interval, and obtain a high-precision spectrum analysis result. In the embodiment of the present application, the first initial vibration acceleration data, the second initial vibration acceleration data, and the third initial vibration acceleration data are subjected to signal zero padding processing, thereby improving the accuracy of the subsequent spectrum analysis result.

[0093] Step S706: Fourier spectrum analysis is performed on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data. The first frequency is the excitation frequency of the turbine in the impeller normal rotation stage before the occurrence of a vibration limit exceeding fault in the offshore turbine, the second frequency is the excitation frequency of the turbine when the vibration limit exceeding fault occurs in the offshore turbine, and the third frequency is the natural frequency of the offshore turbine stop stage. Details can be referred to step S102 of the embodiment shown in FIG. 1, so they will not be described in detail here.

[0094] Step S707: determine a first deviation value between the first frequency and the third frequency, and a second deviation value between the second frequency and the third frequency. For details, refer to step S103 in the embodiment shown in FIG. 1, and will not be described in detail here.

[0095] Step S708: Determine whether a resonance limit exceeding fault occurs in the offshore turbine based on the first deviation value, the second deviation value, and the preset deviation value, and obtain a fault identification result. For details, refer to step S104 in the embodiment shown in FIG. 1, and thus will not be described in detail here.

[0096] The method for identifying vibration limit exceeding faults of offshore wind power turbines according to this embodiment realizes intelligent diagnosis of vibration faults of offshore turbines, and can identify the cause of vibration limit exceeding faults of offshore turbines by analyzing the vibration acceleration data of the offshore turbine, thereby solving the problems in the related art of wasting human resources and taking time caused by manual troubleshooting.

[0097] The following describes specific steps of the method for identifying vibration limit exceeding faults in an offshore wind turbine according to one particular embodiment. Working Example

[0098] Step 1: In the nacelle, two vibration acceleration sensors are arranged symmetrically along the center line of the main shaft and installed according to a redundant design to measure changes in the vibration acceleration of the two components X and Y of the nacelle, an anemometer is arranged on the top of the outside of the nacelle to measure environmental data such as wind speed, the turbine hub rotation speed test module measures the rotation speed data of the turbine impeller, and the pitch angle sensor monitors the pitch angle of the turbine blades.

[0099] Step 2: For vibration acceleration, the monitoring data is recorded in real time at the default frequency of 50Hz. If the turbine is operating normally, the acceleration data is dynamically processed at intervals of 1h, and only the monitoring results for 1s, i.e., a sampling frequency of 1Hz, are retained. If the actual measured acceleration during turbine operation exceeds the set management threshold, it is determined that a vibration limit exceeding fault has occurred, and two minutes of data before and after the limit is exceeded is automatically recorded at a sampling frequency of 50Hz.

[0100] Step 3: Determine whether a jump anomaly occurs in the acceleration data. If there is a sudden change in the amplitude of the four sets of data in the X and Y directions of the two acceleration sensors installed in the turbine nacelle, it indicates that a sensor failure occurs; if the amplitudes of the four sets of data in the X and Y directions of the two acceleration sensors installed in the turbine nacelle are close, the sensor is in good working condition, no jump anomaly occurs in the data, and it is beyond the normal limit, and further spectrum analysis is performed on the data.

[0101] Step 4: Then, perform Fourier spectrum analysis on each of the vibration acceleration components in the two directions X and Y monitored by the sensor to obtain the turbine excitation frequency during the normal impeller rotation phase before the turbine limit is exceeded, the excitation frequency during the limit exceeding phase, and the turbine natural frequency fs within a specified time after the turbine impeller stops. If the deviation between the turbine operating excitation frequency and the natural frequency is within ±5%, it is determined to be a resonance limit exceeding fault, and if the frequency deviation is outside ±5%, it is determined to be a non-resonance limit exceeding fault.

[0102] Step 5: In case of resonance limit exceeding fault, further identify the cause of the fault. Calculate the 1P frequency and 3P frequency bandwidth in the impeller speed range, judge whether the measured natural frequency of the turbine is within the 3P frequency band, if it is within the 3P frequency band, calculate the turbine's 3P resonant speed R3P by the formula R3P=fs*60s / 3, set the 3P resonant speed interval as ±15% of R3P, if there is an overlap between the measured impeller speed before the turbine limit exceeding and the 3P resonant speed interval, it is determined that the cause of the turbine vibration limit exceeding is the 3P self-excited resonance, otherwise it is determined that the turbine has vortex-induced resonance due to external factors such as wind field.

[0103] Step 6: For non-resonant faults, first determine whether the turbine vibration limit exceedance is caused by wind load such as typhoon. If the typhoon factor is excluded, determine that it is caused by the imbalance of the forces received during the rotation of the turbine. The cause is generally a mechanical problem inside the wind turbine, which causes the balance of the forces received by the structure during the rotation of the turbine impeller, such as the loss of synchronization of the individual pitch system, the misalignment of the installation position of the standard zero baseline of the three blades, the wear of the friction contact surface of the main bearing inside the gearbox, insufficient lubrication of the bearing, incorrect lubrication method, unbalanced rotor mass, loose connection parts of the impeller, etc., resulting in a vibration limit exceedance fault. Check the possible faults one by one to identify the cause of the fault.

[0104] Specifically, when performing Fourier FFT spectrum analysis, the length of the data collected on-site is limited, and the frequency resolution often does not meet the requirements, where FFT frequency resolution = sampling frequency / FFT length. In order to improve the accuracy of spectrum analysis, the vibration signal zero padding method is used to add a vibration signal with zero amplitude for a certain period of time to the vibration signal, which can effectively extend the FFT length and shorten the frequency analysis interval to obtain high-precision spectrum analysis results.

[0105] The vibration signal tested in the field by the vibration acceleration sensor contains various noise interference information during the generation and transmission process. Due to the harsh marine environment, it is necessary to filter the time-domain vibration signal during the Fourier spectrum analysis. A low-pass filter is placed as necessary to filter out the high-frequency signal, obtain frequency-domain data within the actual range of the overall frequency of the offshore wind turbine, and eliminate the interference signal.

[0106] Test data from vibration acceleration sensors shows that the marine environment is a harsh environment with severe salt spray and corrosion, which can easily affect the sensor junctions and cause abnormalities in the transmission of data by the sensor. If the data suddenly surges and far exceeds the acceleration management threshold, the control strategy will stop the wind turbine, affecting normal power generation. This problem can be avoided by data analysis, regular maintenance of the sensor, or by connecting the data cable to the sensor using a gold or silver metal connector that is resistant to salt spray and corrosion.

[0107] In this embodiment, an apparatus for identifying vibration limit exceeding faults of an offshore wind turbine is provided to realize the above embodiment and preferred embodiment, and will not be described in detail since it has been described above. As used below, the term "module" may be a combination of software and / or hardware that realizes a certain function. The apparatus described in the following embodiment is preferably implemented in software, but implementation in hardware or a combination of software and hardware is also possible and can be envisioned.

[0108] This embodiment provides an apparatus for identifying vibration limit exceeding faults of offshore wind turbines, and as shown in FIG. 8 , the apparatus includes a first acquisition module 801, a spectrum analysis module 802, a first determination module 803, and a second determination module 804.

[0109] When a vibration limit exceeding failure occurs in an offshore turbine, the first acquisition module 801 acquires first vibration acceleration data within a preset period before the vibration limit exceeding failure occurs in the offshore turbine, second vibration acceleration data during the vibration limit exceeding failure stage, and third vibration acceleration data during the turbine stop stage.

[0110] The spectrum analysis module 802 performs Fourier spectrum analysis on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data. The first frequency is an excitation frequency of the turbine in a normal impeller rotation stage before a vibration limit exceeding fault occurs in the offshore turbine, the second frequency is an excitation frequency of the turbine when a vibration limit exceeding fault occurs in the offshore turbine, and the third frequency is a natural frequency of the offshore turbine in a stopped stage.

[0111] The first determination module 803 determines a first deviation value between the first frequency and the third frequency, and a second deviation value between the second frequency and the third frequency.

[0112] The second determining module 804 determines whether a resonance limit exceeding fault occurs in the offshore turbine according to the first deviation value, the second deviation value and the preset deviation value, and obtains a fault identification result.

[0113] In some preferred embodiments, the apparatus further includes a third determination module that determines a fault treatment recipe based on the fault identification result.

[0114] In some preferred embodiments, the apparatus further includes a fourth determination module that determines a sweep frequency band of the offshore turbine's blades based on a speed range of the offshore turbine's impeller when a resonance limit exceeding fault occurs in the offshore turbine; a first determination module that determines whether a third frequency is within the sweep frequency band; a fifth determination module that determines a resonant speed interval corresponding to the sweep frequency band based on the third frequency when the third frequency is within the sweep frequency band; and a sixth determination module that determines whether a self-excited resonant fault has occurred in the offshore turbine based on the resonant speed interval and the actual measured rotation speed of the impeller before a vibration limit exceeding fault occurred in the offshore turbine.

[0115] In some preferred embodiments, the apparatus further includes a second acquisition module for acquiring vibration acceleration data in a nacelle of the offshore turbine, a comparison module for comparing the vibration acceleration data with respective preset thresholds to obtain a comparison result, and a second judgment module for determining whether a vibration limit exceeding fault has occurred in the offshore turbine based on the comparison result.

[0116] In some preferred embodiments, the apparatus further includes a third acquisition module that acquires vibration acceleration data collected by the first acceleration sensor and vibration acceleration data collected by the second acceleration sensor; a third determination module that determines whether or not an operating status of the first acceleration sensor and the second acceleration sensor is normal based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor; if the operating status of the first acceleration sensor and the second acceleration sensor are normal, a third determination module that determines whether or not a vibration limit exceeding fault has occurred in the offshore turbine based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor; and a transmission module that transmits a shutdown control command to the offshore turbine when it is determined that a vibration limit exceeding fault has occurred in the offshore turbine.

[0117] In some preferred embodiments, the third judgment module includes a comparison unit that compares the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor with predetermined thresholds, respectively, to obtain a comparison result, and a judgment unit that determines that a vibration limit exceeding fault has occurred in the offshore turbine when the vibration acceleration data collected by the first acceleration sensor is greater than the predetermined threshold and / or when the vibration acceleration data collected by the second acceleration sensor is greater than the predetermined threshold.

[0118] The further description of the functions of each of the above modules and units is the same as the corresponding embodiments described above, so they will not be described in detail here.

[0119] In this embodiment, the apparatus for identifying vibration limit exceeding faults in an offshore wind turbine is shown in the form of a functional unit, where unit refers to an Application Specific Integrated Circuit (ASIC), a processor and memory executing one or more software or fixed programs, and / or other devices that may provide the functionality described above.

[0120] An embodiment of the present invention also provides a computing device having an apparatus for identifying vibration limit exceeding faults in an offshore wind turbine as shown in FIG. 8 above.

[0121] Referring to FIG. 9, FIG. 9 is a structural schematic diagram of a computer device according to a possible embodiment of the present invention. As shown in FIG. 9, the computer device includes one or more processors 10, a memory 20, and an interface for connecting each component, including a high-speed interface and a low-speed interface. Each component is communicatively connected to each other using different buses, and may be implemented on a common motherboard or implemented in other ways as needed. The processor may process instructions executed within the computer device, including instructions stored in or on the memory, to display graphical information of a GUI on an external input / output device (e.g., a display device coupled to the interface). In some possible embodiments, multiple processors and / or multiple buses may be used along with multiple memories and multiple memories as needed. Similarly, multiple computer devices may be connected, each device providing a part of the required operations (e.g., as an array of servers, a set of blade servers, or a multiprocessor system). In FIG. 9, one processor 10 is taken as an example.

[0122] The processor 10 may be a central processing unit, a network processor, or a combination thereof. The processor 10 may further include a hardware chip. The hardware chip may be an application specific integrated circuit, a programmable logic device, or a combination thereof. The programmable logic device may be a complex programmable logic device, a field programmable logic gate array, a general purpose array logic, or any combination thereof.

[0123] Among these, the memory 20 stores instructions executable by the at least one processor 10 to cause the at least one processor 10 to perform the methods illustrated in the above embodiments.

[0124] The memory 20 includes a program storage area and a data storage area, where the program storage area can store an operating system, an application program required for at least one function, and the data storage area can store data created by the use of the computer device, etc. Furthermore, the memory 20 includes a high-speed random access memory, and may include non-transient memory, such as at least one magnetic disk memory device, flash memory device, or other non-transient solid-state memory device. In some possible embodiments, the memory 20 may optionally include memory located remotely with respect to the processor 10, and these remote memories may be connected to the computer device via a network. Such networks include, but are not limited to, the Internet, an intranet, a local area network, a mobile communication network, and combinations thereof.

[0125] The memory 20 may include volatile memory, such as random access memory. The memory may also include non-volatile memory, such as flash memory, a hard disk, or a solid state drive. The memory 20 may also include a combination of the above types of memory.

[0126] The computing device further includes a communications interface 30 that allows the computing device to communicate with other devices or with a communications network.

[0127] The embodiments of the present invention further provide a computer readable storage medium, and the methods according to the embodiments of the present invention described above may be implemented in hardware or firmware, or may be realized as computer code that can be recorded in a storage medium or that is originally stored in a remote storage medium or a non-transitory machine readable storage medium downloaded over a network and stored in a local storage medium, whereby the methods described herein may be processed by software stored in a storage medium using a general purpose computer, a dedicated processor, or programmable or dedicated hardware. The storage medium may be a magnetic disk, an optical disk, a read-only storage memory, a random access storage memory, a flash memory, a hard disk or a solid state drive, etc. Furthermore, the storage medium may further include a combination of the above types of memory. It is understood that the computer, the processor, the microprocessor controller, or the programmable hardware includes a storage component that can store or receive the software or computer code, and the software or computer code, when accessed and executed by the computer, the processor, or the hardware, realizes the methods shown in the embodiments above.

[0128] Although the embodiments of the present invention have been described with reference to the accompanying drawings, those skilled in the art may make various modifications and variations without departing from the spirit and scope of the present invention, and all such modifications and variations are intended to be included within the scope defined in the appended claims.

Claims

1. 1. A method for identifying vibration limit exceeding faults in an offshore wind turbine, comprising: When a vibration limit exceeding fault occurs in an offshore turbine, acquiring first vibration acceleration data within a preset period before the vibration limit exceeding fault occurs in the offshore turbine, second vibration acceleration data during a vibration limit exceeding fault stage, and third vibration acceleration data during a turbine stop stage; a step of performing a Fourier spectrum analysis on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data, wherein the first frequency is an excitation frequency of the turbine in an impeller normal rotation phase before a vibration limit exceeding fault occurs in the offshore turbine, the second frequency is an excitation frequency of the turbine when a vibration limit exceeding fault occurs in the offshore turbine, and the third frequency is a natural frequency of the offshore turbine stopped phase; determining a first deviation value between the first frequency and the third frequency and a second deviation value between the second frequency and the third frequency; determining whether a resonance limit exceeding fault has occurred in the offshore turbine based on the first deviation value, the second deviation value, and a preset deviation value, and obtaining a fault identification result.

2. determining whether a resonance limit exceeding fault occurs in the offshore turbine based on the first deviation value, the second deviation value, and a preset deviation value, and obtaining a fault identification result; The method of claim 1 , further comprising the step of determining a fault treatment recipe based on the fault identification results.

3. determining whether a resonance limit exceeding fault occurs in the offshore turbine based on the first deviation value, the second deviation value, and a preset deviation value, and obtaining a fault identification result; determining a sweep frequency band for a blade of the offshore turbine based on a rotation speed range of an impeller of the offshore turbine when a resonance limit exceeding fault occurs in the offshore turbine; determining whether the third frequency is within the swept frequency band; If the third frequency is within a sweep frequency band, determining a resonant rotation speed interval corresponding to the sweep frequency band based on the third frequency; 2. The method of claim 1, further comprising a step of determining whether a self-excited resonant fault has occurred in the offshore turbine based on the resonant speed range and the actual measured impeller speed before a vibration limit exceeding fault occurred in the offshore turbine.

4. before a step of acquiring, in the event of a vibration limit exceeding fault occurring in the offshore turbine, first vibration acceleration data within a target period before the vibration limit exceeding fault occurs in the offshore turbine, second vibration acceleration data in a vibration limit exceeding fault stage, and third vibration acceleration data in a turbine stop stage; acquiring vibration acceleration data within a nacelle of an offshore turbine; comparing the vibration acceleration data with a predetermined threshold value to obtain a comparison result; 2. The method of claim 1, further comprising: determining whether a vibration limit exceeding fault has occurred on the offshore turbine based on the comparison.

5. before a step of acquiring, in the event of a vibration limit exceeding fault occurring in an offshore turbine, first vibration acceleration data within a target period before the occurrence of a vibration limit exceeding fault in the offshore turbine, second vibration acceleration data in a vibration limit exceeding fault stage, and third vibration acceleration data in a turbine stop stage; acquiring vibration acceleration data collected by a first acceleration sensor and vibration acceleration data collected by a second acceleration sensor; determining whether the operation states of the first acceleration sensor and the second acceleration sensor are normal based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor; determining whether a vibration limit exceeding fault has occurred in the offshore turbine based on vibration acceleration data collected by the first acceleration sensor and vibration acceleration data collected by the second acceleration sensor when the operating states of the first acceleration sensor and the second acceleration sensor are normal; The method of claim 1 , further comprising: if determining that the offshore turbine has experienced a vibration limit exceeding fault, sending a shutdown control command to the offshore turbine.

6. The step of determining whether or not a vibration limit exceeding fault has occurred in the offshore turbine based on the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor includes: A step of comparing the vibration acceleration data collected by the first acceleration sensor and the vibration acceleration data collected by the second acceleration sensor with a preset threshold value, respectively, to obtain a comparison result; and determining that a vibration limit exceeding fault has occurred in the offshore turbine if the vibration acceleration data collected by the first acceleration sensor is greater than a preset threshold and / or if the vibration acceleration data collected by the second acceleration sensor is greater than a preset threshold.

7. When a vibration limit exceeding fault occurs in an offshore turbine, a step of acquiring first vibration acceleration data within a preset period before the vibration limit exceeding fault occurs in the offshore turbine, second vibration acceleration data during a vibration limit exceeding fault stage, and third vibration acceleration data during a turbine stop stage, When a vibration limit exceeding fault occurs in an offshore turbine, acquiring first initial vibration acceleration data within a preset period before the vibration limit exceeding fault occurs in the offshore turbine, second initial vibration acceleration data in a vibration limit exceeding fault stage, and third initial vibration acceleration data in a turbine stop stage; 2. The method according to claim 1, further comprising: performing signal zero padding processing on each of the first initial vibration acceleration data, the second initial vibration acceleration data, and the third initial vibration acceleration data to obtain first vibration acceleration data corresponding to the first initial vibration acceleration data, second vibration acceleration data corresponding to the second initial vibration acceleration data, and third vibration acceleration data corresponding to the third initial vibration acceleration data.

8. An apparatus for identifying vibration limit exceeding faults in an offshore wind turbine, comprising: a first acquisition module for acquiring, when a vibration limit exceeding fault occurs in an offshore turbine, first vibration acceleration data within a preset period before the vibration limit exceeding fault occurs in the offshore turbine, second vibration acceleration data during a vibration limit exceeding fault stage, and third vibration acceleration data during a turbine stop stage; a spectrum analysis module that performs Fourier spectrum analysis on each of the first vibration acceleration data, the second vibration acceleration data, and the third vibration acceleration data to obtain a first frequency corresponding to the first vibration acceleration data, a second frequency corresponding to the second vibration acceleration data, and a third frequency corresponding to the third vibration acceleration data, wherein the first frequency is an excitation frequency of the turbine in an impeller normal rotation phase before a vibration limit exceeding fault occurs in the offshore turbine, the second frequency is an excitation frequency of the turbine when a vibration limit exceeding fault occurs in the offshore turbine, and the third frequency is a natural frequency of the offshore turbine stopped phase; a first determination module that determines a first deviation value between the first frequency and the third frequency and a second deviation value between the second frequency and the third frequency; and a second determination module that determines whether a resonance limit exceeding fault has occurred in the offshore turbine based on the first deviation value, the second deviation value, and a preset deviation value, and obtains a fault identification result.

9. The apparatus of claim 8 , further comprising a third determination module for determining a fault treatment recipe based on the fault identification result.

10. 8. A computer device comprising: a memory; and a processor, the memory and the processor being communicatively connected to each other, the memory having computer instructions stored therein, the processor executing the computer instructions to perform the method for identifying vibration limit exceeding faults in an offshore wind turbine according to any one of claims 1 to 7.

11. A computer readable storage medium having stored thereon computer instructions for causing a computer to carry out the method for identifying vibration limit exceeding faults in an offshore wind turbine according to any one of claims 1 to 7.

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