Transfer function determination method, wind condition detection method, and wind turbine generator set

Abstract

The present application provides a transfer function determination method, a wind condition detection method, a device, a wind turbine generator set, and a readable storage medium. The transfer function determination method includes simulating the overall external flow field of the wind turbine generator set based on the computational fluid dynamics model of the wind turbine generator set to obtain a simulated airflow field, wherein different simulated airflow fields correspond to different simulated incoming wind conditions of the wind turbine generator set. The computational fluid dynamics model includes a wind turbine generator set model and a wind tunnel model. The wind tunnel model includes a wind tunnel model region, and the wind turbine generator set model is disposed in the wind tunnel model region. The wind turbine generator set model includes simulated wind measurement points; determining the simulated wind speed measurement values and simulated wind direction measurement values corresponding to the simulated wind measurement points respectively under a plurality of different simulated incoming wind conditions; and determining the wind speed transfer function and the wind direction transfer function of the wind turbine generator set at the simulated wind measurement points based on the simulated wind speed measurement values and the simulated wind direction measurement values. The power generation of the wind turbine generator set can be improved.

Description

Technical Field

[0001] The present invention relates to the field of wind power, and in particular, to a method for determining a transfer function, a method for detecting wind conditions, a device, a wind turbine generator set, and a readable storage medium. Background Art

[0002] The measured wind speed and wind direction of a wind turbine generator set are important factors for the overall control of the unit. They not only directly determine the cut-in and cut-out of the wind turbine generator set, but also indirectly affect the wind alignment effect of the wind turbine generator set, and further affect the power generation of the wind turbine generator set.

[0003] The wind speed and wind direction measuring devices of wind turbine generator sets mainly include mechanical anemometers, ultrasonic anemometers, and nacelle lidar anemometers. However, due to the high cost of nacelle lidar anemometers, they do not yet have the basis for large-scale application. Therefore, wind turbine generator sets mainly collect wind speed and wind direction data through mechanical anemometers or ultrasonic anemometers installed at the top of the nacelle. During the operation of these two types of anemometers, the wind wheel, the nacelle shape of the wind turbine generator set, and the environmental terrain where the wind turbine generator set is located will interfere with the flow field at the position of the anemometer, resulting in a deviation between the wind speed and wind direction detected by the anemometer and the incoming flow wind speed and wind direction. In some technologies, a transfer function is established to describe the relationship between the wind speed and wind direction detected by the anemometer and the incoming flow wind speed and wind direction. In this way, through the transfer function, the wind speed and wind direction detected by the anemometer can be corrected before being used in the control link of the wind turbine generator set.

[0004] However, for such wind turbine generator sets based on the transfer function, the power generation still needs to be improved. Summary of the Invention

[0005] The present application provides a method for determining a transfer function, a method for detecting wind conditions, a device, a wind turbine generator set, and a readable storage medium, which can improve the power generation of wind turbine generator sets.

[0006] The present application provides a method for determining a transfer function, and the method for determining the transfer function includes:

[0007] Based on the computational fluid dynamics model of the wind turbine generator set, simulate the overall external flow field of the wind turbine generator set to obtain a simulated airflow field, wherein different simulated airflow fields correspond to different simulated incoming flow wind conditions of the wind turbine generator set. The computational fluid dynamics model includes a wind turbine generator set model and a wind tunnel model. The wind tunnel model includes a wind tunnel model area, the wind turbine generator set model is disposed in the wind tunnel model area, and the wind turbine generator set model includes simulated anemometry points;

[0008] Determine the corresponding simulated wind speed measurement values and simulated wind direction measurement values at the simulated wind measurement points under multiple different simulated oncoming wind conditions;

[0009] Based on the simulated wind speed measurement values and the simulated wind direction measurement values, determine the wind speed transfer function and the wind direction transfer function of the wind turbine at the simulated wind measurement point.

[0010] This application provides a wind condition detection method, and the wind condition detection method includes:

[0011] Obtain the wind speed measurement value and the direction measurement value of the wind turbine at the wind measurement point;

[0012] Based on the wind speed measurement value and a preset wind speed transfer function, determine the wind speed at the wind measurement point, and based on the direction measurement value and a preset wind direction transfer function, determine the wind direction at the wind measurement point, where the wind speed transfer function and / or the wind direction transfer function are determined based on the transfer function determination method described above.

[0013] This application provides a device, and the device includes one or more processors for implementing the transfer function determination method or the wind condition detection method described in any one of the above.

[0014] This application provides a readable storage medium, and a program is stored on the readable storage medium. When the program is executed by a processor, the transfer function determination method or the wind condition detection method described in any one of the above is implemented.

[0015] In some embodiments of this application, based on the computational fluid dynamics model of the wind turbine, simulate the external flow field of the entire wind turbine. According to the corresponding simulated wind speed measurement values and simulated wind direction measurement values at the simulated wind measurement points, a relatively accurate transfer function can be obtained in the early design stage of the wind turbine, so that the data collected by the anemometer can be corrected in the early stage when the wind turbine is put into operation, and then the wind turbine can be accurately controlled to improve the power generation of the wind turbine. Description of the Drawings

[0016] Figure 1 is a structural schematic diagram of a wind turbine;

[0017] Figure 2 is a flowchart of the transfer function determination method provided by an embodiment of this application;

[0018] Figure 3 is a schematic diagram of the computational fluid dynamics model provided by an embodiment of this application;

[0019] Figure 4 is Figure 3 a partial schematic diagram of the computational fluid dynamics model in

[0020] Figure 5 Yes Figure 3 Schematic diagram of the wind turbine model included in the computational fluid dynamics model in

[0021] Figure 6 Flowchart of the wind condition detection method provided by an embodiment of the present application;

[0022] Figure 7 Block diagram of the device provided by an embodiment of the present application. Detailed implementation mode

[0023] Here, the exemplary embodiments will be described in detail, and the examples are shown in the drawings. When the following description refers to the drawings, unless otherwise indicated, the same numbers in different drawings represent the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with one or more embodiments of this specification. On the contrary, they are merely examples of devices and methods consistent with some aspects of one or more embodiments of this specification as detailed in the appended claims.

[0024] It should be noted that: in other embodiments, the steps of the corresponding methods are not necessarily executed in the order shown and described in this specification. In some other embodiments, the steps included in the method may be more or less than those described in this specification. In addition, a single step described in this specification may be decomposed into multiple steps for description in other embodiments; and multiple steps described in this specification may also be combined into a single step for description in other embodiments.

[0025] Figure 1 Is a schematic structural diagram of a wind turbine 100. See Figure 1 , the wind turbine generator set 100 is also called a wind turbine, and includes a tower 11 extending from a support system 14, a nacelle 12 installed on the tower 11, and a wind wheel 13 connected to the nacelle 12. The wind wheel 13 includes a rotatable hub 131 connected to the nacelle 12 and at least one wind wheel blade 132 connected to the hub 131 and extending outward from the hub 131. The wind wheel blade 132 can drive the hub 131 to rotate, so that kinetic energy can be converted from wind energy into available mechanical energy and then into electrical energy.

[0026] In some embodiments, an anemometer 121 is provided at the tail of the nacelle 12 for measuring the wind speed and wind direction at the anemometry point A above the nacelle 12. The detected wind speed and wind direction usually pass through transfer function correction before being used to control the wind turbine 100. In this way, in order to avoid the problem that the air flow field at the anemometry point A is disturbed by the wind wheel 13, the nacelle 12 shape, etc., and the wind speed and wind direction data detected by the anemometer 121 are inaccurate.

[0027] Figure 2 The flowchart of the transfer function determination method provided by an embodiment of the present application. The transfer function determination method can be applied to an electronic device, such as a computer. Based on the transfer function determined by the transfer function determination method, it can be applied to Figure 1 the wind turbine 100 in

[0028] Step S21: Based on the computational fluid dynamics model of the wind turbine 100, simulate the external flow field of the entire wind turbine 100 to obtain a simulated airflow field. Among them, different simulated airflow fields correspond to different simulated incoming wind conditions of the wind turbine 100. The computational fluid dynamics model includes a wind turbine model and a wind tunnel model. The wind tunnel model includes a wind tunnel model area, and the wind turbine model is arranged in the wind tunnel model area. The wind turbine model includes simulated wind measurement points.

[0029] Combined with reference Figures 3 to 5 . Figure 3 The schematic diagram of the computational fluid dynamics model 300 provided by an embodiment of the present application. Figure 4 It is Figure 3 the partial schematic diagram of the computational fluid dynamics model 300 in Figure 5 It is Figure 3 the schematic diagram of the wind turbine model 33 included in the computational fluid dynamics model 300 in

[0030] Reference Figure 3 , in some embodiments, the computational fluid dynamics model 300 is a three-dimensional solid simulation model. Simulating the external flow field of the entire wind turbine 100 based on the computational fluid dynamics model 300 means simulating the airflow field in the external space area of the wind turbine 100. In this way, the simulated airflow field of the wind turbine 100 can be obtained. In different simulated airflow fields, the air flow velocity, direction, etc. are different, corresponding to different simulated incoming wind conditions of the wind turbine 100. The simulated incoming wind conditions refer to the incoming wind conditions of the simulated wind turbine 100, including the simulated incoming wind speed and the simulated incoming wind direction.

[0031] In some embodiments, the simulated airflow field can be generated by the wind tunnel model of the computational fluid dynamics model 300. The wind tunnel model includes a wind tunnel model region 31, a wind tunnel inlet 32, and a wind tunnel outlet 36. The wind tunnel inlet 32 communicates with the wind tunnel outlet 36 through the wind tunnel model region 31. The simulated airflow field flows into the wind tunnel model region 31 from the wind tunnel inlet 32 and flows out of the wind tunnel model region 31 from the wind tunnel outlet 36. The simulated wind condition at the wind tunnel inlet 32 is the simulated oncoming wind condition of the wind turbine generator set 100. The wind turbine generator set model 33 refers to the model of the wind turbine generator set 100. By arranging the wind turbine generator set model 33 in the wind tunnel model region 31, the scenario where the wind turbine generator set 100 is located in the airflow field can be simulated.

[0032] In some embodiments, the computational fluid dynamics model 300 further includes a simulation support system 34. The simulation support system 34 is used to simulate the support for the wind turbine generator set 100. In this embodiment, the simulation support system 34 is a simulated ground plane.

[0033] In some embodiments, the computational fluid dynamics model 300 can be created according to the following steps:

[0034] 1) Create the wind turbine generator set model 33. Refer to Figure 5 , in some embodiments, the wind turbine generator set model 33 is an external shape simulation model. This model is used to simulate the external shape of the wind turbine generator set 100, and specifically may include the simulated external shape of the wind turbine blades 331, the simulated external shape of the hub fairing 334, the simulated external shape of the nacelle cover 333, and the simulated external shape of the tower 335. Additionally, in the case where a cooling tower is provided above the nacelle 12 of the wind turbine generator set 100, the wind turbine generator set model 33 may further include the simulated external shape of the cooling tower 332. The wind turbine generator set model 33 is a model obtained by combining the simulated external shapes of the above components. The simulated wind measurement point is located at one of the positions above the simulated external shape of the nacelle cover 333 (such as Figure 3 the position of point B in Figure 1 ) and is used to simulate the wind measurement point A in

[0035] In some embodiments, the overall model of the wind turbine generator set 100 can be geometrically cleaned, and unnecessary geometric details can be deleted to obtain the simulated external shapes of the above Figure 5 described components, and the external shapes of the components are combined to obtain the wind turbine generator set model 33.

[0036] 2) Create a wind tunnel model and place the wind turbine generator model 33 in the wind tunnel model area 31. Specifically, the wind tunnel model area 31 is divided into a rotating area 311 and a non-rotating area 312. The simulated outer shape 331 of the wind turbine blades and the simulated outer shape 334 of the hub fairing of the wind turbine generator model 33 are arranged in the rotating area 311, and the simulated outer shapes of other components of the wind turbine generator model 33 except the simulated outer shape 331 of the wind turbine blades and the simulated outer shape 334 of the hub fairing are arranged in the non-rotating area 312. Among them, the process of arranging the simulated outer shape 331 of the wind turbine blades and the simulated outer shape 334 of the hub fairing in the rotating area 311 is to first create a simulated wind wheel disc 35 in the rotating area 311, and then arrange the simulated outer shape 331 of the wind turbine blades and the simulated outer shape 334 of the hub fairing in the simulated wind wheel disc 35. The simulated wind wheel disc 35 can rotate along the simulated wind turbine rotation axis 336 and can form an angle with the simulated ground plane. When the simulated wind wheel disc 35 rotates, it can interfere with the simulated wind direction and simulated wind speed at the simulated wind measurement point. In this way, the scenario where the wind speed and wind direction at the wind measurement point A of the wind turbine generator 100 are interfered can be simulated.

[0037] Further, the simulated wind wheel disc 35 includes a simulated wind wheel surface 351. The simulated wind wheel surface 351 serves as a middle interface for separating the rotating area 311 and the non-rotating area 312. The hydrodynamic calculation data of the rotating area 311 and the non-rotating area 312 can be transmitted through the simulated wind wheel surface 351.

[0038] 3) Perform mesh division on the above-mentioned rotating area 311 and non-rotating area 312. In the computational fluid dynamics model, the rotating area 311 and the non-rotating area 312 can be meshed according to the required simulation accuracy. For example, if a high simulation accuracy is required, the number of mesh divisions of the rotating area 311 and the non-rotating area 312 can be increased.

[0039] 4) Set the wind tunnel model area 31 that has completed mesh division. Specifically, it includes boundary condition setting, rotation speed setting of the rotating area 311, air density setting, turbulence model setting, and initial condition setting. In the case where the wind turbine generator 100 includes a cooling tower, it also includes cooling tower pressure drop setting.

[0040] In some embodiments, the boundary condition setting includes middle interface setting, simulation wind speed setting at the wind tunnel inlet 32 (i.e., simulation incoming flow wind speed setting), and pressure magnitude setting at the wind tunnel outlet 36. Among them,

[0041] In some embodiments, the middle interface setting refers to setting the simulated wind wheel surface 351 of the rotating area and the simulated wind wheel surface 351 of the non-rotating area 312 as middle interfaces, and pairing the middle interfaces of the two areas so as to transmit the hydrodynamic calculation data of the two areas through the middle interface.

[0042] In some embodiments, the simulation wind speed setting at the wind tunnel inlet 32 refers to establishing a correspondence between the simulation wind speed at the simulation outer shape 334 of the hub fairing and the simulation wind speed at the wind tunnel inlet 32. In this way, when simulating the external flow field of the entire wind turbine generator set 100, the simulation wind speed at the wind tunnel inlet 32 of the computational fluid dynamics model 300 can be determined according to the simulation wind speed at the simulation outer shape 334 of the hub fairing of the wind turbine generator set model 33. The setting can be carried out according to Expression (1):

[0043] v(z) = v hub (z / z hub ) α (1)

[0044] Wherein,

[0045] v(z) represents the simulation wind speed at different grid points on the wind tunnel inlet 32.

[0046] z represents the height of different grid points on the wind tunnel inlet 32 relative to the simulated ground plane. In Figure 3 , z represents the coordinate height of different grid points on the wind tunnel inlet 32 in the Z-axis direction. The Z-axis is perpendicular to the simulated ground plane, the X-axis and the Y-axis are perpendicular, and the plane formed is parallel to the simulated ground plane. The height of the simulated ground plane in the Z-axis direction is 0.

[0047] z hub represents the height of the center point of the simulation outer shape 334 of the hub fairing relative to the simulated ground plane. In Figure 3 z hub represents the coordinate height of the center point of the simulation outer shape 334 of the hub fairing in the Z-axis direction.

[0048] v hub represents the simulation wind speed at the center point position of the simulation outer shape 334 of the hub fairing.

[0049] It should be noted that the simulation wind speed at the wind tunnel inlet 32 determined by Expression (1) is a scalar, that is, it represents the magnitude of the simulation wind speed at the wind tunnel inlet 32.

[0050] In some embodiments, the rotational speed setting of the rotation area 311 refers to establishing a correspondence between the simulation wind speed at the wind tunnel inlet 32 and the rotational speed of the rotation area 311 according to the simulation wind speed at the wind tunnel inlet 32, the model of the simulated wind turbine generator set 100, etc. When the simulation wind speed at the wind tunnel inlet 32 is different, or the model of the simulated wind turbine generator set 100 is different, the rotational speed of the rotation area 311 is different.

[0051] In some embodiments, the air density setting refers to setting the simulated air density in the wind tunnel model area 31 to simulate the air density in the external space area of the wind turbine generator 100.

[0052] In some embodiments, the turbulence model setting is used to establish the relationship between the simulated incoming wind conditions and the simulated wind speed and simulated pressure at each grid point in the wind tunnel model area 31. For the same grid point, different turbulence models may result in different simulated wind speeds and simulated pressures at that grid point.

[0053] In some embodiments, the initial condition setting includes, but is not limited to, setting the simulated incoming wind speed for the iterative calculation of the computational fluid dynamics model to start. In some embodiments, after the computational fluid dynamics model 300 is created, the model needs to be verified, such as verifying the model grid division, the geometric assembly of the wind turbine generator model 33, the model settings, etc. After the model is verified correctly, step S22 is executed.

[0054] Step S22: Determine the simulated wind speed measurement values and simulated wind direction measurement values corresponding to the simulated wind measurement points respectively under multiple different simulated incoming wind conditions.

[0055] Continue to refer to Figures 2 to 5 In some embodiments, through Figure 3 the relevant description, it can be known that the simulated incoming wind conditions are the simulated wind conditions at the wind tunnel inlet 32, including the simulated wind speed and simulated wind direction at the wind tunnel inlet 32. Among them, the simulated wind speed at the wind tunnel inlet 32 can be determined by the above expression (1). Based on this, multiple different simulated incoming wind conditions can be obtained by the following method:

[0056] 1) In the wind speed interval in which the wind turbine generator 100 operates, determine a wind speed point at every preset wind speed interval as the simulated wind speed at the hub fairing simulation outer shape 334.

[0057] In some embodiments, the wind speed interval in which the wind turbine generator 100 operates refers to the interval between the cut-in wind speed and the cut-out wind speed of the wind turbine generator 100. For example, if the cut-in wind speed of the wind turbine generator 100 is 2 m / s and the cut-out wind speed is 20 m / s, then the wind speed interval in which the wind turbine generator 100 operates is [2 m / s, 20 m / s]. In some other embodiments, the wind speed interval may not be determined according to the cut-in wind speed and cut-out wind speed of the wind turbine generator 100. For example, the wind speed interval can be determined as the interval between the minimum wind speed and the maximum wind speed in the environment where the wind turbine generator 100 is located.

[0058] In some embodiments, the preset wind speed interval can be set to 2 m / s. That is, within the wind speed range in which the wind turbine operates, a wind speed point is determined every 2 m / s as the simulated wind speed at the simulated shape 334 of the hub fairing. For example, assuming that the wind speed range in which the wind turbine 100 operates is [2 m / s, 20 m / s] and the preset wind speed interval is 2 m / s, the wind speed points are 2 m / s, 4 m / s, …… 18 m / s, 20 m / s. These wind speed points are respectively used as the simulated wind speeds v hub1 、v hub2 、……、v hubn at the simulated shape 334 of the hub fairing.

[0059] It should be noted that the preset wind speed interval can be determined according to the actual situation. For example, the preset wind speed interval can also be 1 m / s or 3 m / s.

[0060] 2) Based on each simulated wind speed at the simulated shape 334 of the hub fairing, determine the simulated wind speeds at the wind tunnel inlet 32 respectively.

[0061] In some embodiments, substitute the simulated wind speeds at the simulated shape 334 of the hub fairing determined in step 1) into the above expression (1) respectively to obtain multiple simulated wind speeds v(z) 1 、v(z) 2 ……、v(z) n at the wind tunnel inlet 32, that is, the simulated oncoming flow wind speeds v(z) 1 、v(z) 2 ……、v(z) n . Where n is the number of simulated oncoming flow wind speeds.

[0062] 3) In the wind direction range in which the wind turbine 100 operates, determine a wind direction point every preset wind direction interval as the simulated wind direction at the wind tunnel inlet 32.

[0063] In some embodiments, the wind direction in which the wind turbine 100 operates refers to the oncoming flow wind direction when the wind turbine 100 operates. Assuming that the due east is the 0-degree direction of the wind direction and the preset wind direction interval is set to 10 degrees, rotating clockwise, a wind direction point is determined every 10 degrees, then 10 degrees, 20 degrees …… 360 degrees can be determined as the simulated wind directions at the wind tunnel inlet 32. Specifically, in Figure 3 , in the XY plane, starting from the direction of the X-axis and rotating clockwise, a simulated wind direction at the wind tunnel inlet 32 can be determined every 10 degrees. In this way, multiple simulated wind directions a 1 、a 2 、……、a m at the wind tunnel inlet 32 can be determined, that is, the simulated oncoming flow wind directions a 1 、a 2 、……、am Among them, m is the number of simulated oncoming wind directions.

[0064] It should be noted that the preset wind direction interval can be determined according to the actual situation. For example, the preset wind direction interval can also be 5 degrees or 15 degrees.

[0065] 4) For multiple different combinations of the simulated wind speed and simulated wind direction at the wind tunnel inlet 32, each combination is taken as a simulated oncoming wind condition.

[0066] In some embodiments, the n simulated wind speeds v(z) at the wind tunnel inlet 32 determined in step 2) above 1 、v(z) 2 ……、v(z) n are combined with the m simulated wind directions a at the wind tunnel inlet 32 determined in step 3) 1 、a 2 、……、a m A combination of a simulated wind speed and a simulated wind direction is a simulated condition at the wind tunnel inlet 32, that is, a simulated oncoming wind condition. In this way, n*m simulated oncoming wind conditions can be obtained.

[0067] Furthermore, with the rotation area 311 kept rotating, the obtained n*m simulated oncoming wind conditions are respectively subjected to simulation calculations through the computational fluid dynamics model 300 to obtain the X-axis simulated wind speed vector along the X-axis and the Y-axis simulated wind speed vector along the Y-axis at the simulated wind measurement point under each simulated oncoming wind condition. Then, the X-axis simulated wind speed vector and the Y-axis simulated wind speed vector under each simulated oncoming wind condition are vectorially summed to obtain the simulated wind speed measurement value and the simulated wind direction measurement value respectively corresponding to the simulated wind measurement point under each simulated oncoming wind condition. In this way, n*m simulated wind speed measurement values and simulated wind direction measurement values can be obtained. Among them, the obtained n*m simulated wind speed measurement values and simulated wind direction measurement values represent the wind speed and wind direction at the simulated wind measurement point obtained by simulation under n*m simulated oncoming wind conditions.

[0068] In some embodiments, the simulated wind speed measurement values and simulated wind direction measurement values at the simulated wind measurement point obtained by the above method are relatively comprehensive in data and can accurately reflect the wind speed and wind direction after the airflow field at the wind measurement point A is disturbed under various different oncoming wind conditions of the wind turbine 100.

[0069] Step S23, based on the simulated wind speed measurement values and simulated wind direction measurement values, determine the wind speed transfer function and wind direction transfer function of the wind turbine 100 at the simulated wind measurement point.

[0070] In some embodiments, the simulated wind speed measurement values are fitted to obtain a wind speed transfer function; the simulated wind direction measurement values are fitted to obtain a wind direction transfer function. Specifically, the least squares method can be used to fit the simulated wind speed measurement values to obtain the wind speed transfer function. Similarly, the least squares method is used to fit the simulated wind direction measurement values to obtain the wind direction transfer function.

[0071] In some embodiments, it is assumed that the simulated wind speed at the simulated outer shape 334 of the hub fairing is v hubi ; the simulated wind direction at the wind tunnel inlet 32, that is, the simulated oncoming flow wind direction is a j ; and when the simulated wind speed at the simulated outer shape 334 of the hub fairing is v hubi , and the simulated oncoming flow wind direction is a j , the simulated wind speed measurement value at the simulated wind measurement point is V i，j , and the simulated wind direction measurement value is A i，j . Wherein, i belongs to positive integers from 1 to n, and j belongs to positive integers from 1 to m.

[0072] The wind speed transfer function can be expressed as expression (2):

[0073]

[0074] Wherein,

[0075] f(V i，j ) represents the corrected simulated wind speed measurement value at the simulated wind measurement point when the simulated wind speed measurement value at the simulated wind measurement point is V i，j ;

[0076] f(V i，j ) - v hubi represents the difference between the corrected simulated wind speed measurement values f(V hubi ), f(V 1 ),..., f(V 2 ),..., f(V j ) at the simulated wind measurement point and the simulated wind speed v i，1 ) at the simulated outer shape 334 of the hub fairing at various simulated oncoming flow wind directions a i，2 ), a i，j ),..., a hubi ;

[0077] b 1 , c 1 can be obtained according to the least squares fitting result.

[0078] The wind direction transfer function can be expressed as expression (3):

[0079]

[0080] Among them,

[0081] g(A i，j ) represents the corrected simulated wind direction measurement value at the simulated wind measurement point when the simulated wind direction measurement value at the simulated wind measurement point is A i，j ;

[0082] g(A i，j ) - a j represents the different simulated wind speeds v j at the simulated outer shape 334 of the hub fairing when the simulated oncoming flow wind direction is a hub1 、v hub2 ……、v hubi , and the differences between the corrected simulated wind direction measurement values g(A 1，j ), g(A 2，j )……、g(A ，j ) at the simulated wind measurement point and the simulated wind direction a j at the simulated outer shape 334 of the hub fairing;

[0083] b 2 、c 2 can be obtained according to the least squares fitting result.

[0084] In some embodiments of the present application, based on the computational fluid dynamics model of the wind turbine 100, the external flow field of the entire wind turbine 100 is simulated. According to the simulated wind speed measurement value and the simulated wind direction measurement value corresponding to the simulated wind measurement point respectively, a relatively accurate transfer function can be obtained in the preliminary design stage of the wind turbine 100, so that in the early stage of the operation of the wind turbine 100, the data collected by the anemometer 121 can be corrected, and then the wind turbine 100 can be accurately controlled, improving the power generation of the wind turbine 100. In addition, the present application determines the transfer function of the wind turbine 100 based on the simulation method, which can obtain the transfer function without statistically analyzing the operation data of the wind turbine 100, avoiding collecting the accurate wind speed and wind direction at the wind measurement point A through an expensive laser anemometer in the early stage of the operation of the wind turbine 100 to statistically obtain the transfer function, achieving the purpose of reducing the cost of the wind turbine 100.

[0085] Figure 6 is a flowchart of a wind condition detection method provided by an embodiment of the present application. The wind condition detection method can be applied to the controller of the wind turbine 100 and includes step S61 and step S62.

[0086] Step S61, obtaining the wind speed measurement value and the direction measurement value at the wind measurement point A of the wind turbine 100.

[0087] In some embodiments, the measured wind speed value is the wind speed detected by the anemometer 121 of the wind turbine 100 at the wind measurement point A; the measured direction value is the wind direction detected by the anemometer 121 of the wind turbine 100 at the wind measurement point A. The controller of the wind turbine 100 is communicatively connected to the anemometer 121 to obtain the wind speed and wind direction detected by the anemometer 121.

[0088] Step S62, based on the measured wind speed value and a preset wind speed transfer function, determine the wind speed at the wind measurement point A, and based on the measured direction value and a preset wind direction transfer function, determine the wind direction at the wind measurement point A, where the wind speed transfer function and / or the wind direction transfer function are determined based on the above transfer function determination method.

[0089] In the wind condition detection method of the present application, since the transfer function is determined based on the above transfer function determination method, the beneficial effects related to the above transfer function determination method can be achieved, such as reducing the cost of the wind turbine 100, increasing the power generation of the wind turbine 100, etc. For specific details, reference can be made to the above description of the function determination method, which will not be elaborated here.

[0090] Figure 7 It is a block diagram of a module of the device 700 provided by an embodiment of the present application.

[0091] The device 700 includes one or more processors 701 for implementing the transfer function determination method or the wind condition detection method described above. In some embodiments, the device 700 may include a readable storage medium 709, and the readable storage medium 709 may store a program that can be called by the processor 701, and may include a non-volatile storage medium.

[0092] In some embodiments, the device 700 may include a memory 708 and an interface 707.

[0093] In some embodiments, the device 700 may further include other hardware according to actual applications.

[0094] In some embodiments, the device 700 may be the controller of the wind turbine 100 or an electronic device, such as a computer.

[0095] The readable storage medium 709 of the embodiment of the present application stores a program thereon, and when the program is executed by the processor 701, it is used to implement the transfer function determination method or the wind condition detection method described above.

[0096] The present application may be embodied in the form of a computer program product implemented on one or more readable storage media 709 including program code (including but not limited to disk storage, CD-ROM, optical storage, etc.). The readable storage media 709 includes permanent and non-permanent, removable and non-removable media, and information storage can be implemented by any method or technology. The information may be computer-readable instructions, data structures, program modules, or other data. Examples of the readable storage media 709 include but are not limited to: phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technologies, compact disc read-only memory (CD-ROM), digital versatile disc (DVD) or other optical storage, magnetic cassette tapes, magnetic tape magnetic disk storage or other magnetic storage devices, or any other non-transmission media that can be used to store information accessible by a computing device.

[0097] The above are only the preferred embodiments of this specification and are not intended to limit this specification. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of this specification shall be included within the scope of protection of this specification.

[0098] It should also be noted that the term "comprising", "including" or any other variation thereof is intended to cover non-exclusive inclusion, such that a process, method, article or device comprising a series of elements not only includes those elements but also includes other elements not expressly listed, or further includes elements inherent to such process, method, article or device. Without further limitation, an element defined by the statement "comprising an..." does not exclude the presence of additional identical elements in the process, method, article or device comprising the element.

Claims

1. A method for determining a transfer function, characterized in that, the method for determining the transfer function includes: Based on the computational fluid dynamics model of a wind turbine generator set, simulating the overall external flow field of the wind turbine generator set to obtain a simulated airflow field, wherein different simulated airflow fields correspond to different simulated incoming wind conditions of the wind turbine generator set. The computational fluid dynamics model includes a wind turbine generator set model and a wind tunnel model. The wind tunnel model includes a wind tunnel model area, and the wind turbine generator set model is disposed in the wind tunnel model area. The wind turbine generator set model includes simulated wind measurement points; Determining the simulated wind speed measurement values and simulated wind direction measurement values respectively corresponding to the simulated wind measurement points under a plurality of different simulated incoming wind conditions; and Based on the simulated wind speed measurement values and the simulated wind direction measurement values, determining the wind speed transfer function and the wind direction transfer function of the wind turbine generator set at the simulated wind measurement points; wherein, the wind tunnel model includes a wind tunnel entrance; the simulating the overall external flow field of the wind turbine generator set includes: Determining the simulated wind speed at the wind tunnel entrance according to the simulated wind speed at the simulated hub fairing of the wind turbine generator set model.

2. The method for determining a transfer function according to claim 1, characterized in that, the wind tunnel model area is divided into a rotating area and a non-rotating area. The simulated outer shapes of the wind turbine blades and the hub fairing of the wind turbine generator set model are disposed in the rotating area, and the simulated outer shapes of other components of the wind turbine generator set model except the simulated outer shapes of the wind turbine blades and the hub fairing are disposed in the non-rotating area.

3. The method for determining a transfer function according to claim 1, characterized in that, the plurality of different simulated incoming wind conditions are simulated based on the following method: In the wind speed interval in which the wind turbine generator set operates, determining a wind speed point at every preset wind speed interval as the simulated wind speed at the simulated hub fairing; Based on each of the simulated wind speeds at the simulated hub fairing, respectively determining the simulated wind speed at the wind tunnel entrance; In the wind direction interval in which the wind turbine generator set operates, determining a wind direction point at every preset wind direction interval as the simulated wind direction at the wind tunnel entrance; For multiple different combinations of the simulated wind speed and the simulated wind direction at the wind tunnel entrance, taking each combination as one of the simulated incoming wind conditions.

4. The method for determining a transfer function according to claim 1, characterized in that, the determining the wind speed transfer function and the wind direction transfer function of the wind turbine generator set at the simulated wind measurement points based on the simulated wind speed measurement values and the simulated wind direction measurement values includes: Performing fitting on the simulated wind speed measurement values to obtain the wind speed transfer function; Performing fitting on the simulated wind direction measurement values to obtain the wind direction transfer function.

5. The method for determining a transfer function according to claim 4, characterized in that, the performing fitting on the simulated wind speed measurement values to obtain the wind speed transfer function includes: Based on the least squares method, performing fitting on the simulated wind speed measurement values to obtain the wind speed transfer function; and / or Performing fitting on the simulated wind direction measurement values to obtain the wind direction transfer function includes: Based on the least squares method, performing fitting on the simulated wind direction measurement values to obtain the wind direction transfer function.

6. A wind condition detection method for a wind turbine generator, characterized in that, the wind condition detection method includes: obtaining the wind speed measurement value and the direction measurement value at the wind measurement point of the wind turbine generator; and based on the wind speed measurement value and the preset wind speed transfer function, determining the wind speed at the wind measurement point, and based on the direction measurement value and the preset wind direction transfer function, determining the wind direction at the wind measurement point, wherein the wind speed transfer function and / or the wind direction transfer function are determined based on the transfer function determination method in claim 1.

7. A device, characterized in that, it includes one or more processors for implementing the transfer function determination method described in any one of claims 1-5, or for implementing the wind condition detection method described in claim 6.

8. The device according to claim 7, characterized in that, the device includes a controller of the wind turbine generator.

9. A wind turbine generator, characterized in that, it includes the controller described in claim 8.

10. A readable storage medium, characterized in that, a program is stored thereon, and when the program is executed by a processor, it implements the transfer function determination method described in any one of claims 1-5, or implements the wind condition detection method described in claim 6.

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