Load evaluation method and device for wind turbine generator

Abstract

The invention discloses a load evaluation method and device for a wind turbine generator, and belongs to the technical field of wind power. The method comprises the steps that the wind speed corresponding to at least one measuring point in a first area and the wind speed corresponding to at least one measuring point in a second area are acquired, the first area comprises the area above the height of a hub in the height direction, the second area comprises the area below the height of the hub in the height direction, and the heights of different measuring points are different; obtaining equivalent turbulence based on the wind speed corresponding to the measuring point in the first area and the wind speed corresponding to the measuring point in the second area; and determining the load of the wind turbine generator according to the equivalent turbulence. According to the embodiment of the invention, the accuracy of load evaluation can be improved.

Description

Technical Field

[0001] The present application relates to the field of wind power technology, and in particular to a method and device for load assessment of a wind turbine generator set. Background Art

[0002] The load on a wind turbine refers to the forces and moments acting on its various components. Wind turbine loads are primarily derived from wind, gravity, inertia, and various dynamic effects during turbine operation. Currently, the turbulence at the turbine hub is used as input to determine the turbine load. However, as wind turbines grow larger, the turbulence distribution on the turbine blade surface no longer meets the assumption of spatial uniformity. This results in significant deviations between the turbine load derived from the turbulence at the turbine hub and the actual load, reducing the accuracy of turbine load assessment. Summary of the Invention

[0003] The embodiments of the present application provide a method and device for load assessment of a wind turbine generator set, which can improve the accuracy of load assessment.

[0004] In a first aspect, an embodiment of the present application provides a load assessment method for a wind turbine generator set, including: obtaining the wind speed corresponding to at least one measuring point in a first area and the wind speed corresponding to at least one measuring point in a second area, the first area including the area above the hub height in the height direction, the second area including the area below the hub height in the height direction, and the heights of different measuring points are different; obtaining equivalent turbulence based on the wind speed corresponding to the measuring point in the first area and the wind speed corresponding to the measuring point in the second area; and determining the load of the wind turbine generator set based on the equivalent turbulence.

[0005] In some possible embodiments, the measuring points include actual measuring points, or the measuring points include actual measuring points and virtual measuring points; when the number of actual measuring points in the first area is different from the number of actual measuring points in the second area, the measuring points in the first target area with fewer actual measuring points include the actual measuring points and virtual measuring points in the first target area, and the turbulence corresponding to the virtual measuring points is obtained based on the turbulence corresponding to the actual measuring points in the first target area or the turbulence corresponding to the hub height, wherein the first target area is one of the first area and the second area.

[0006] In some possible embodiments, the method further includes: searching for an actual measuring point in the first target area that is opposite or approximately opposite to the actual measuring point in the second target area based on the hub height, where the second target area is the other of the first area and the second area; if the first target area lacks an actual measuring point that is opposite or approximately opposite to the actual measuring point in the second target area, setting a virtual measuring point in the second target area at a position opposite or approximately opposite to the actual measuring point, and determining the turbulence corresponding to the set virtual measuring point based on the turbulence corresponding to the actual measuring point adjacent to the set virtual measuring point or the turbulence corresponding to the hub height.

[0007] In some possible embodiments, if the height of the virtual measuring point in the first area is higher than the height of any actual measuring point in the first area, the turbulence corresponding to the virtual measuring point in the first area is the same as the turbulence corresponding to the actual measuring point with the highest height in the first area; if the height of the virtual measuring point in the second area is lower than the height of any actual measuring point in the second area, the turbulence corresponding to the virtual measuring point in the second area is the same as the turbulence corresponding to the actual measuring point with the lowest height in the second area.

[0008] In some possible embodiments, in the height direction, the measuring points in the first area and the measuring points in the second area are arranged symmetrically or approximately symmetrically with the hub height as the symmetry axis.

[0009] In some possible embodiments, equivalent turbulence is obtained based on the wind speed corresponding to the height of the measuring point in the first area and the wind speed corresponding to the height of the measuring point in the second area, including: obtaining the turbulence corresponding to the measuring point in the first area according to the wind speed corresponding to the measuring point in the first area; obtaining the turbulence corresponding to the measuring point in the second area according to the wind speed corresponding to the measuring point in the second area; and using a weighted algorithm to process the turbulence corresponding to the measuring point in the first area and the turbulence corresponding to the measuring point in the second area to obtain equivalent turbulence.

[0010] In some possible embodiments, the method further includes: obtaining the wind speed corresponding to the hub height; obtaining equivalent turbulence based on the wind speed corresponding to the height of the measuring point in the first area and the wind speed corresponding to the height of the measuring point in the second area, including: obtaining equivalent turbulence based on the wind speed corresponding to the hub height, the wind speed corresponding to the height of the measuring point in the first area, and the wind speed corresponding to the height of the measuring point in the second area.

[0011] In some possible embodiments, the wind speed corresponding to the measuring point is measured by a wind measuring device in the wind farm; the method also includes: determining the load of the wind turbine in the wind farm based on equivalent turbulence, position information of the wind measuring device and the wind turbine in the wind farm, and unit information of the wind turbine in the wind farm.

[0012] In some possible embodiments, the method further includes: if the load of the wind turbine set exceeds a preset safe load range, controlling the wind turbine set to operate at a reduced load; and / or, when the load of the wind turbine set is the load of the wind turbine set in a simulated wind farm, if the load of the wind turbine set does not meet the safe load conditions of the wind farm, updating the unit design parameters of the wind turbine set until the load of the wind turbine set determined based on the equivalent turbulence meets the safe load conditions of the wind farm.

[0013] In a second aspect, an embodiment of the present application provides a load assessment device for a wind turbine generator set, comprising: a processor and a memory storing computer program instructions; when the processor executes the computer program instructions, the load assessment method for the wind turbine generator set of the first aspect is implemented.

[0014] The embodiment of the present application provides a load assessment method and device for a wind turbine generator set, which obtains the wind speed corresponding to the measuring point in the area above the hub height and the wind speed corresponding to the measuring point in the area below the hub height, and combines the wind speeds corresponding to the measuring points in the area above the hub height and the area below the hub height to obtain the equivalent turbulence of the entire impeller surface. Since the wind speeds at different heights on the impeller surface are different, the wind speeds in the area above the hub height and the area below the hub height can be combined to reflect the wind speed conditions of the entire impeller surface. Turbulence is the standard deviation of wind speed. Correspondingly, the turbulence at different heights on the impeller surface is also different. The equivalent turbulence obtained based on the wind speeds of multiple measuring points in the area above the hub height and the area below the hub height can more accurately reflect the turbulence conditions of the entire impeller surface. Using equivalent turbulence to replace the single-point turbulence at the hub center for load assessment can reduce the impact of turbulence non-uniformity within the impeller surface, thereby improving the accuracy of load assessment. BRIEF DESCRIPTION OF THE DRAWINGS

[0015] In order to more clearly illustrate the technical solutions of the embodiments of the present application, the following is a brief introduction to the drawings required for use in the embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without any creative work.

[0016] Figure 1 A flow chart of a method for evaluating the load of a wind turbine generator system according to an embodiment of the present application;

[0017] Figure 2 Schematic diagram of turbulence and equivalent turbulence at multiple actual measurement points in Example 1 of an embodiment of the present application;

[0018] Figure 3 This is a schematic diagram comparing loads obtained by evaluating the two methods in Example 1 of the embodiment of the present application;

[0019] Figure 4 Schematic diagram of turbulence and equivalent turbulence at multiple actual measurement points in Example 2 of an embodiment of the present application;

[0020] Figure 5 This is a schematic diagram comparing loads obtained by evaluating the two methods in Example 1 of the embodiment of the present application;

[0021] Figure 6 A schematic diagram of an example of a load assessment process for a wind turbine generator system provided in an embodiment of the present application;

[0022] Figure 7 A schematic structural diagram of a load assessment device for a wind turbine generator system according to an embodiment of the present application;

[0023] Figure 8 A schematic diagram of the structure of load assessment of a wind turbine generator set provided in one embodiment of the present application. DETAILED DESCRIPTION

[0024] The features and exemplary embodiments of various aspects of the present application will be described in detail below. In order to make the purpose, technical solutions and advantages of the present application clearer, the present application will be further described in detail below in conjunction with the accompanying drawings and specific embodiments. It should be understood that the specific embodiments described herein are only intended to explain the present application, rather than to limit the present application. For those skilled in the art, the present application can be implemented without the need for some of these specific details. The following description of the embodiments is merely to provide a better understanding of the present application by illustrating the examples of the present application.

[0025] The load on a wind turbine refers to the forces and moments acting on its various components. The load on a wind turbine is primarily derived from wind, gravity, inertia, and various dynamic effects during turbine operation. Currently, turbulence at the turbine hub is used as input for evaluating wind turbine loads. However, as wind turbines grow larger, the diameter of their impellers increases. The turbulence distribution on the turbine impeller surface no longer meets the assumption of spatial uniformity. Consequently, the load derived from the turbulence at the turbine hub deviates significantly from the actual load, reducing the accuracy of wind turbine load assessment.

[0026] The present application provides a load assessment method, equipment, device and storage medium for a wind turbine set, which can obtain turbulence corresponding to multiple corresponding heights based on the wind speeds corresponding to multiple measuring points at corresponding heights for the turbulence distribution within the impeller surface that no longer conforms to spatial uniformity. The equivalent turbulence obtained by the turbulence corresponding to multiple corresponding heights is used to replace the single-point turbulence at the height of the hub center to perform load assessment, thereby reducing the impact of uneven turbulence within the impeller surface on load assessment and improving the accuracy of load assessment.

[0027] The load assessment method, equipment, device and storage medium for a wind turbine generator system provided in this application are described below.

[0028] The present application provides a load assessment method for a wind turbine, which can be used in scenarios where load assessment of wind turbines in a wind farm is performed. The load assessment method for a wind turbine can be executed by a load assessment device, equipment, system, etc. of the wind turbine, and is not limited here. Figure 1 A flow chart of a method for evaluating the load of a wind turbine generator system according to an embodiment of the present application is provided. Figure 1 As shown, the load assessment method for a wind turbine generator set may include steps S101 to S103.

[0029] In step S101 , a wind speed corresponding to at least one measuring point in a first area and a wind speed corresponding to at least one measuring point in a second area are obtained.

[0030] The first area includes the area above the hub height in the height direction. The second area includes the area below the hub height in the height direction. The height direction here refers to the height direction of the wind turbine. The hub height may refer to the height of the hub center. At least one measuring point is set in the first area, and at least one measuring point is set in the second area. The heights of different measuring points are different. For example, the hub height is 100 meters, that is, the height of the hub center is 100 meters, and the measuring points include measuring points at a height of 30 meters, a height of 50 meters, a height of 80 meters, a height of 120 meters, and a height of 150 meters. Then, the height area above 100 meters is the first area, and the height area below 100 meters is the second area. The measuring points in the first area include measuring points at a height of 120 meters and a height of 150 meters, and the measuring points in the second area include measuring points at a height of 30 meters, a height of 50 meters, and a height of 80 meters. The wind speed corresponding to the measuring point can be obtained by using a wind measuring device. The wind measuring device may include but is not limited to a wind tower, a wind radar, etc. Any device that can measure the wind speed at different heights is within the protection scope of the embodiments of the present application. The number and setting method of the wind measuring device are not limited here. For example, multiple wind turbines can share the same wind measuring device, or a wind measuring device is set up for each wind turbine. For each measuring point, the wind speed of the measuring point at each collection moment within a preset time period can be collected, and the average of the wind speed of the measuring point at all collection moments within the preset time period is used as the wind speed corresponding to the measuring point. The preset time period can be determined according to the scenario, needs, experience, etc., and is not limited here. For example, the preset time period can be 10 minutes. It should be noted that the wind speed needs to be collected at the same collection moment for different measuring points.

[0031] In some examples, the measuring points may include actual measuring points. Actual measuring points are actually existing measuring points, and the actual measuring points are determined according to the capabilities of the wind measuring device. For example, the measuring points set by the wind measuring device itself are actual measuring points, and the number of actual measuring points is consistent with the number of measuring points set by the wind measuring device. The wind speed corresponding to the actual measuring point can be directly measured by the wind measuring device. In other examples, the measuring points may include actual measuring points and virtual measuring points. Virtual measuring points are non-actual measuring points, that is, the wind measuring device does not set an actual measuring point at the height corresponding to the virtual measuring point. The wind speed corresponding to the virtual measuring point is not directly measured by the wind measuring device, but is determined based on the wind speed corresponding to the actual measuring point adjacent to the virtual measuring point. In some cases, if the actual measuring point meets the preset load assessment requirements, you can only focus on the actual measuring point, obtain the wind speed corresponding to the actual measuring point, and execute subsequent processes based on the wind speed corresponding to the actual measuring point. In some cases, if the actual measurement point does not meet the preset load assessment requirements, it is necessary to add a virtual measurement point to obtain the wind speed corresponding to the actual measurement point and the wind speed corresponding to the virtual measurement point. The subsequent process is executed based on the wind speed corresponding to the actual measurement point and the wind speed corresponding to the virtual measurement point. It should be noted that after adding a virtual measurement point, the turbulence corresponding to the virtual measurement point can also be obtained based on the turbulence calculated based on the wind speed corresponding to the actual measurement point.

[0032] In step S102 , equivalent turbulence is obtained based on the wind speed corresponding to the measuring point in the first area and the wind speed corresponding to the measuring point in the second area.

[0033] The turbulence corresponding to the measuring point can be calculated based on the wind speed corresponding to the measuring point. The turbulence corresponding to a measuring point can be the standard deviation of the wind speed corresponding to the measuring point. The turbulence corresponding to each measuring point can be first obtained based on the wind speed corresponding to each measuring point, and then the equivalent turbulence can be calculated by combining the turbulence corresponding to all measuring points. The equivalent turbulence can be the equivalent turbulence of the impeller surface used for load assessment of the wind turbine. In some examples, under the same conditions, the higher the height of the measuring point, the smaller the turbulence corresponding to the measuring point; the lower the height of the measuring point, the larger the turbulence corresponding to the measuring point. The equivalent turbulence is greater than the turbulence calculated based on the wind speed corresponding to the measuring point with the highest height in the first area, and is less than the turbulence calculated based on the wind speed corresponding to the measuring point with the lowest height in the second area. Compared with using the turbulence corresponding to the hub height to reflect the turbulence conditions of the impeller surface, the equivalent turbulence can reflect the turbulence conditions of the impeller surface more accurately.

[0034] In some examples, the wind speed corresponding to the hub height can also be obtained, and the hub center is also used as a measuring point. According to the wind speed corresponding to the hub height, the wind speed corresponding to the height of the measuring point in the first area, and the wind speed corresponding to the height of the measuring point in the second area, the equivalent turbulence is obtained. Specifically, the turbulence corresponding to the hub height can be obtained according to the wind speed corresponding to the hub height; the turbulence corresponding to the height of the measuring point in the first area can be obtained according to the wind speed corresponding to the height of the measuring point in the first area; the turbulence corresponding to the height of the measuring point in the second area can be obtained according to the wind speed corresponding to the height of the measuring point in the second area; the equivalent turbulence is obtained by combining the turbulence corresponding to the hub height, the turbulence corresponding to the height of each measuring point in the first area, and the turbulence corresponding to the height of each measuring point in the second area.

[0035] In some examples, the turbulence corresponding to a measuring point can be calculated based on the wind speed corresponding to the measuring point, and the turbulence corresponding to each measuring point can be processed using a weighted algorithm to obtain equivalent turbulence. For example, the measuring points include measuring points in a first region and measuring points in a second region. The turbulence corresponding to the measuring point in the first region can be obtained based on the wind speed corresponding to the measuring point in the first region; the turbulence corresponding to the measuring point in the second region can be obtained based on the wind speed corresponding to the measuring point in the second region; the turbulence corresponding to the measuring point in the first region and the turbulence corresponding to the measuring point in the second region can be processed using a weighted algorithm to obtain equivalent turbulence. For another example, the measuring points include the hub center, measuring points in the first region, and measuring points in the second region. The turbulence corresponding to the hub height can be obtained based on the wind speed corresponding to the hub height; the turbulence corresponding to the measuring point in the first region can be obtained based on the wind speed corresponding to the measuring point in the first region; the turbulence corresponding to the measuring point in the second region can be obtained based on the wind speed corresponding to the measuring point in the second region; the turbulence corresponding to the hub height, the turbulence corresponding to the measuring point in the first region, and the turbulence corresponding to the measuring point in the second region can be processed using a weighted algorithm to obtain equivalent turbulence. The weighting coefficients for turbulence at each measurement point in the weighted algorithm can be the same, meaning the equivalent turbulence is the average of the turbulence at each measurement point. The weighting coefficients for turbulence at each measurement point in the weighted algorithm can also be different, depending on the specific scenario, needs, and experience, and are not limited here.

[0036] In other examples, the turbulence corresponding to measuring points at different heights in historical data and the equivalent turbulence training that can ensure the accuracy of load assessment meet the requirements can be used in advance to obtain an equivalent turbulence processing model. The turbulence corresponding to the measuring point is calculated based on the wind speed corresponding to the measuring point obtained this time, and the turbulence corresponding to each measuring point is input into the equivalent turbulence processing model, and the turbulence output by the equivalent turbulence processing model is determined as the equivalent turbulence.

[0037] It should be noted that the measuring points in the above embodiment may include measuring points in the first area and measuring points in the second area. Alternatively, the measuring points may include the hub center, measuring points in the first area, and measuring points in the second area.

[0038] In step S103 , the load of the wind turbine is determined according to the equivalent turbulence.

[0039] There is a physical correlation between equivalent turbulence and the load of a wind turbine. The load of the wind turbine can be determined based on the equivalent turbulence and this physical correlation. In some examples, if multiple wind turbines share a wind measuring device, the load of the wind turbine can be determined based on the equivalent turbulence, the unit information of each wind turbine, the location information of the wind measuring device, and the location information of each wind turbine. In some examples, if each wind turbine is equipped with a corresponding wind measuring device, the load of each wind turbine can be determined based on the equivalent turbulence, the unit information of the wind turbine, the location information of the wind measuring device, and the location information of the wind turbine. In some examples, the wind measuring device may be installed on the wind turbine. The load of the wind turbine can be determined based on the equivalent turbulence, the location information of the wind turbine, and the unit information of the wind turbine. In some examples, the wind measuring device may be located a certain distance from the wind turbine. The load of the wind turbine can be determined based on the equivalent turbulence, the unit information of the wind turbine, and the location relationship between the wind turbine and the wind measuring device.

[0040] In an embodiment of the present application, the wind speed corresponding to the measuring point in the area above the hub height and the wind speed corresponding to the measuring point in the area below the hub height are obtained, and the wind speed corresponding to the measuring point in the area above the hub height and the area below the hub height are combined to obtain the equivalent turbulence of the entire impeller surface. Since the wind speed at different heights on the impeller surface is different, the wind speed in the area above the hub height and the area below the hub height can be combined to reflect the wind speed of the entire impeller surface. Turbulence is the standard deviation of wind speed. Correspondingly, the turbulence at different heights on the impeller surface is also different. The equivalent turbulence obtained based on the wind speed of multiple measuring points in the area above the hub height and the area below the hub height can more accurately reflect the turbulence of the entire impeller surface. Using equivalent turbulence to replace the single-point turbulence at the hub center for load assessment can reduce the impact of turbulence non-uniformity within the impeller surface, thereby improving the accuracy of load assessment. Moreover, the load assessment method for the wind turbine in the embodiment of the present application does not require additional wind parameter simulation within the impeller surface, making the operation simpler and easier to execute.

[0041] In some embodiments, the measured points may include actual measured points, or the measured points may include actual measured points and virtual measured points.

[0042] If the number of actual measurement points in the first area is the same as the number of actual measurement points in the second area, there is no need to set up virtual measurement points. That is, if the number of actual measurement points in the first area is the same as the number of actual measurement points in the second area, the measurement points in the first area include the actual measurement points in the first area, and the measurement points in the second area include the actual measurement points in the second area. Accordingly, equivalent turbulence can be derived based on the wind speeds corresponding to the actual measurement points in the first area and the wind speeds corresponding to the actual measurement points in the second area.

[0043] If the number of actual measurement points in the first area differs from the number of actual measurement points in the second area, virtual measurement points need to be set in the area with fewer actual measurement points to ensure that the number of measurement points in the first area is consistent with the number of measurement points in the second area. That is, if the number of actual measurement points in the first area differs from the number of actual measurement points in the second area, the measurement points in the first target area with fewer actual measurement points include both actual measurement points and virtual measurement points in the first target area, while the measurement points in the second target area with more actual measurement points include the actual measurement points in the second target area. The first target area is one of the first and second areas, and the second target area is the other of the first and second areas. The first target area is the area with fewer actual measurement points, and the second target area is the area with more actual measurement points. The turbulence corresponding to the virtual measurement point is derived based on the wind speed corresponding to the actual measurement point in the first target area or the turbulence corresponding to the hub height. Furthermore, the turbulence corresponding to the virtual measurement point can be determined based on the turbulence corresponding to the adjacent actual measurement point and the positional relationship between the virtual measurement point and the actual measurement point. Alternatively, the turbulence corresponding to the virtual measurement point can be derived based on the turbulence corresponding to the hub height. Since the turbulence at the measuring point is obtained based on the wind speed at the measuring point, it can also be said that the wind speed corresponding to the virtual measuring point is obtained based on the wind speed corresponding to the actual measuring point in the first target area or the wind speed corresponding to the hub height. Furthermore, the wind speed corresponding to the virtual measuring point can be determined based on the wind speed corresponding to the actual measuring point adjacent to it and the positional relationship between the virtual measuring point and the actual measuring point, or the wind speed corresponding to the virtual measuring point can be obtained based on the wind speed corresponding to the hub height.

[0044] In some embodiments, a virtual measuring point can be set in the first target area so that a measuring point in the first target area is relative or approximately relative to a measuring point in the second target area. Specifically, the hub height can be used to search for an actual measuring point in the first target area that is relative or approximately relative to an actual measuring point in the second target area. If the first target area lacks an actual measuring point that is relative or approximately relative to the actual measuring point in the second target area, a virtual measuring point can be set in the second target area at a position relative or approximately relative to the actual measuring point, and the turbulence corresponding to the set virtual measuring point is determined based on the turbulence corresponding to the actual measuring point adjacent to the set virtual measuring point or the turbulence corresponding to the hub height. The relative position of a measuring point in the first target area and a measuring point in the second target area means that the first distance and the second distance are equal, the first distance being the distance between the height of the measuring point in the first target area and the hub height, and the second distance being the distance between the height of the measuring point in the second target area and the hub height. The measuring point in the first target area and the measuring point in the second target area are approximately relative to each other, which means that the difference between the first distance and the second distance is within a preset difference range. The preset difference range can be set according to the scenario, requirements, experience, etc. For example, the preset difference range can be [-2 meters, 2 meters], but is not limited to this example.

[0045] In some examples, if the number of actual measurement points in the first target area is zero, the turbulence corresponding to the virtual measurement points in the first target area is the same as the turbulence corresponding to the wheel hub height, the turbulence corresponding to the highest actual measurement point in the second target area, or the turbulence corresponding to the lowest actual measurement point in the second target area. The number of actual measurement points in the first target area is zero, indicating that there are no actual measurement points in the first target area, that is, all measurement points in the first target area are virtual measurement points. If there are actual measurement points at wheel hub height, the turbulence corresponding to the wheel hub height can be determined as the turbulence corresponding to the height of each virtual measurement point in the first target area. For example, the hub height is 100 meters, the first target area is the first area and there are no actual measuring points in the first area, and the second area includes two actual measuring points, which are the actual measuring point at 50 meters and the actual measuring point at 80 meters. The hub height, i.e., 100 meters, can be used as a reference to set virtual measuring points at 120 meters and 150 meters in the first area, and the turbulence corresponding to the virtual measuring point at 120 meters is set as the turbulence corresponding to the hub height, and the turbulence corresponding to the virtual measuring point at 150 meters is set as the turbulence corresponding to the hub height. If there is no actual measuring point at the hub height, and the first target area is the first area, the turbulence corresponding to the highest actual measuring point in the second area can be determined as the turbulence corresponding to the height of each virtual measuring point in the first target area. If there is no actual measuring point at the hub height, and the first target area is the second area, the turbulence corresponding to the lowest actual measuring point in the first area can be determined as the turbulence corresponding to the height of each virtual measuring point in the first target area.

[0046] In some examples, if the height of the virtual measuring point in the first area is higher than the height of any actual measuring point in the first area, the turbulence corresponding to the virtual measuring point in the first area is the same as the turbulence corresponding to the highest actual measuring point in the first area. In the case where the first area lacks an actual measuring point that is symmetrical or approximately symmetrical to the actual measuring point in the second area, and the position corresponding to the actual measuring point missing in the first area is higher than all the actual measuring points in the first area, it is necessary to set a virtual measuring point above the highest actual measuring point in the first area, and the turbulence corresponding to the set virtual measuring point can be the turbulence corresponding to the highest actual measuring point in the first area. For example, if the hub height is 100 meters, the second area includes an actual measuring point at a height of 50 meters and an actual measuring point at a height of 80 meters, and the first area only has an actual measuring point at a height of 120 meters, then it is necessary to set a virtual measuring point at a height of 150 meters, and set the turbulence corresponding to the virtual measuring point at a height of 150 meters to be the same as the turbulence corresponding to the actual measuring point at a height of 120 meters.

[0047] In some examples, if the height of the virtual measuring point in the second area is lower than the height of any actual measuring point in the second area, the turbulence corresponding to the virtual measuring point in the second area is the same as the turbulence corresponding to the lowest actual measuring point in the second area. In the case where the second area lacks an actual measuring point that is symmetrical or approximately symmetrical to the actual measuring point in the first area and the position corresponding to the missing actual measuring point in the second area is lower than all the actual measuring points in the second area, it is necessary to set a virtual measuring point below the lowest actual measuring point in the second area, and the turbulence corresponding to the set virtual measuring point can be the turbulence corresponding to the lowest actual measuring point in the second area. For example, if the hub height is 100 meters, the second area includes actual measuring points at an altitude of 80 meters, and the first area includes actual measuring points at an altitude of 120 meters and actual measuring points at an altitude of 150 meters, then it is necessary to set a virtual measuring point at an altitude of 50 meters, and set the turbulence corresponding to the virtual measuring point at an altitude of 50 meters to be the same as the turbulence corresponding to the actual measuring point at an altitude of 80 meters.

[0048] In some examples, if a virtual measuring point in the first target area has actual measuring points above and below it, the turbulence corresponding to the virtual measuring point can be calculated based on the turbulence corresponding to the actual measuring points above and below the virtual measuring point. An interpolation algorithm or a fitting algorithm can be used to calculate the turbulence corresponding to the actual measuring points above and below the virtual measuring point. If a virtual measuring point in the first target area has actual measuring points above and below it, the turbulence corresponding to the virtual measuring point can also be calculated based on the wind speeds corresponding to more actual measuring points above and below the virtual measuring point. The more actual measuring points above and below the virtual measuring point may include more actual measuring points in addition to the two adjacent actual measuring points. An interpolation algorithm or a fitting algorithm can be used to calculate the turbulence corresponding to the more actual measuring points above and below the virtual measuring point.

[0049] In some embodiments, the measuring points in the first region are symmetrically arranged or approximately symmetrically arranged with the measuring points in the second region about the hub height as the axis of symmetry. The measuring points in the first region are approximately symmetrically arranged with the measuring points in the second region about the hub height as the axis of symmetry, which means that the measuring points in the first region and the measuring points in the second region are symmetrically arranged with the hub height as the axis of symmetry within an acceptable error range. For example, if the hub height is 100 meters, the measuring points in the first region are symmetrically arranged with the total measuring points in the second region, the first region includes measuring points at an altitude of 110 meters, a measuring point at an altitude of 120 meters, and a measuring point at an altitude of 130 meters, and the second region includes measuring points at an altitude of 90 meters, a measuring point at an altitude of 80 meters, and a measuring point at an altitude of 70 meters. For another example, if the hub height is 100 meters, the measuring points in the first region are approximately symmetrically arranged with the total measuring points in the second region, the first region includes measuring points at an altitude of 110 meters, a measuring point at an altitude of 119 meters, and a measuring point at an altitude of 132 meters, and the second region includes measuring points at an altitude of 90 meters, a measuring point at an altitude of 80 meters, and a measuring point at an altitude of 70 meters. The symmetrical arrangement of the measuring points in the first area and the measuring points in the second area can make the equivalent turbulence obtained according to the wind speed corresponding to the measuring points in the first area and the wind speed corresponding to the measuring points in the second area more consistent with the actual turbulence conditions on the impeller surface, that is, the equivalent turbulence is more accurate, thereby making the evaluated load of the wind turbine more accurate.

[0050] For ease of understanding, two examples are used below to illustrate the effect of the load assessment method for a wind turbine generator set in the embodiment of the present application on improving the accuracy of load assessment.

[0051] In Example 1, there are no actual measuring points in the first area, and the second area includes three actual measuring points. The three actual measuring points in the second area are the actual measuring point at the lower blade tip position of the wind turbine, the actual measuring point at a height of 50 meters, and the actual measuring point at a height of 80 meters. The height of the actual measuring point at the lower blade tip position is the height of the blade tip of the wind turbine blade from the bottom surface when it is at an azimuth angle of 180°, that is, vertically downward. The height of the actual measuring point at the lower blade tip position is less than 50 meters. The position of the hub height is also an actual measuring point, and the hub height is greater than 80 meters. Figure 2 Schematic diagram of turbulence and equivalent turbulence at multiple actual measurement points in Example 1 of the embodiment of the present application, Figure 3 This is a schematic diagram comparing the loads obtained by evaluating the two methods in Example 1 of the embodiment of the present application. Figure 3 The load involved is the tower My load of the wind turbine which is most affected by turbulence. Figure 2 The horizontal axis is the wind speed in meters per second, and the vertical axis is the turbulence in meters per second; Figure 2The lower blade tip turbulence is the turbulence calculated based on the wind speed corresponding to the actual measurement point at the lower blade tip position, the turbulence at 50 meters height is the turbulence calculated based on the wind speed corresponding to the actual measurement point at 50 meters height, the turbulence at 80 meters height is the turbulence calculated based on the wind speed corresponding to the actual measurement point at 80 meters height, the turbulence at hub height is the turbulence calculated based on the wind speed at hub height, and the equivalent turbulence is the equivalent turbulence obtained by the load assessment method of the wind turbine set in the embodiment of the present application. Figure 2 It can be seen that in areas with lower wind speeds, such as wind speeds less than 10 m / s, the turbulence and equivalent turbulence corresponding to actual measuring points at different heights are not much different; in areas with higher wind speeds, such as wind speeds greater than or equal to 10 m / s, the turbulence corresponding to actual measuring points with higher heights is relatively lower, and the turbulence corresponding to actual measuring points with lower heights is relatively higher, and the equivalent turbulence is higher than the turbulence at the hub height. Figure 3 The horizontal axis is the wind speed, in meters per second, and the vertical axis is the ratio of the evaluated load to the measured load, in percent. The two load evaluation methods in Example 1 include Method 1 and Method 2. Method 1 is a load evaluation method that uses the turbulence corresponding to the hub height as the equivalent turbulence of the impeller surface. Method 2 is a load evaluation method that uses the equivalent turbulence obtained based on the wind speed corresponding to the measuring point in the first area and the wind speed corresponding to the measuring point in the second area in the embodiment of the present application as the equivalent turbulence of the impeller surface. Figure 3 It can be seen that in areas with lower wind speeds, such as wind speeds less than 10 m / s, the ratio of the load obtained by evaluation using method one to the measured load is not much different from the ratio of the load obtained by evaluation using method two to the measured load. However, in areas with higher wind speeds, such as wind speeds greater than or equal to 10 m / s, the difference between the ratio of the load obtained by evaluation using method one and the measured load and 100% is relatively larger, and the difference between the ratio of the load obtained by evaluation using method two and the measured load and 100% is relatively smaller. The deviation between the load obtained by using method two, i.e., the load evaluation method for the wind turbine generator set in the embodiment of the present application, and the measured load is reduced by 2% to 9% under various wind speed conditions. That is to say, the deviation between the load obtained by using the load evaluation method for the wind turbine generator set in the embodiment of the present application and the measured load is smaller, the load obtained by using the load evaluation method for the wind turbine generator set in the embodiment of the present application is closer to the measured load, and the load obtained by the load evaluation method for the wind turbine generator set in the embodiment of the present application is more accurate.

[0052] In Example 2, the first area includes three actual measuring points, which are respectively the actual measuring point at an altitude of 160 meters, the actual measuring point at an altitude of 180 meters, and the actual measuring point at an altitude of 200 meters. The second area includes four actual measuring points, which are respectively the lower blade tip position measuring point of the wind turbine, the actual measuring point at an altitude of 50 meters, the actual measuring point at an altitude of 70 meters, and the actual measuring point at an altitude of 90 meters. The description of the height of the actual measuring point at the lower blade tip position can be found above and will not be repeated here. The position of the hub height is also an actual measuring point, and the hub height is greater than 90 meters.

[0053] Figure 4 Schematic diagram of turbulence and equivalent turbulence at multiple actual measurement points in Example 2 of the embodiment of the present application, Figure 5 This is a schematic diagram comparing the loads obtained by evaluating the two methods in Example 1 of the embodiment of the present application. Figure 5 The load involved is the tower My load of the wind turbine which is most affected by turbulence. Figure 4 The horizontal axis is the wind speed in meters per second, and the vertical axis is the turbulence in meters per second; Figure 4 The lower tip turbulence is the turbulence calculated based on the wind speed corresponding to the measuring point at the lower tip position, the turbulence at 50 meters height is the turbulence calculated based on the wind speed corresponding to the measuring point at 50 meters height, the turbulence at 70 meters height is the turbulence calculated based on the wind speed corresponding to the measuring point at 70 meters height, the turbulence at 90 meters height is the turbulence calculated based on the wind speed corresponding to the measuring point at 90 meters height, the turbulence at hub height is the turbulence calculated based on the wind speed at hub height, the equivalent turbulence is the equivalent turbulence obtained by the load assessment method of the wind turbine set in the embodiment of the present application, the turbulence at 160 meters height is the turbulence calculated based on the wind speed corresponding to the measuring point at 160 meters height, the turbulence at 180 meters height is the turbulence calculated based on the wind speed corresponding to the measuring point at 180 meters height, and the turbulence at 200 meters height is the turbulence calculated based on the wind speed corresponding to the measuring point at 200 meters height. Figure 4 It can be seen that in areas with higher wind speeds, such as wind speeds greater than or equal to 13 m / s, the higher the actual measuring point, the lower the corresponding turbulence, and the lower the actual measuring point, the higher the corresponding turbulence. The equivalent turbulence is higher than the turbulence at the hub height. Figure 5 The horizontal axis is the wind speed, in meters per second, and the vertical axis is the ratio of the evaluated load to the measured load, in percent. The two load evaluation methods in Example 2 include Method 1 and Method 2. Method 1 is a load evaluation method that uses the turbulence corresponding to the hub height as the equivalent turbulence of the impeller surface. Method 2 is a load evaluation method that uses the equivalent turbulence obtained based on the wind speed corresponding to the measuring point in the first area and the wind speed corresponding to the measuring point in the second area in the embodiment of the present application as the equivalent turbulence of the impeller surface. Figure 5It can be seen that in areas with lower wind speeds, such as wind speeds less than 13 m / s, the ratio of the load obtained by evaluation using method one to the measured load is not much different from the ratio of the load obtained by evaluation using method two to the measured load. However, in areas with higher wind speeds, such as wind speeds greater than or equal to 13 m / s, the difference between the ratio of the load obtained by evaluation using method one and the measured load and 100% is relatively larger, and the difference between the ratio of the load obtained by evaluation using method two and the measured load and 100% is relatively smaller. The deviation between the load obtained by using method two, i.e., the load evaluation method for the wind turbine generator set in the embodiment of the present application, and the measured load is reduced by 2% to 6% under various wind speed conditions. That is to say, the deviation between the load obtained by using the load evaluation method for the wind turbine generator set in the embodiment of the present application and the measured load is smaller, the load obtained by using the load evaluation method for the wind turbine generator set in the embodiment of the present application is closer to the measured load, and the load obtained by the load evaluation method for the wind turbine generator set in the embodiment of the present application is more accurate.

[0054] In some embodiments, it can also be determined based on the wind speed corresponding to the measuring point whether to use the equivalent turbulence obtained based on the wind speed corresponding to the measuring point in the first area and the wind speed corresponding to the measuring point in the second area for load assessment, or to use the turbulence calculated based on the wind speed corresponding to the hub height as the equivalent turbulence for load assessment. Because in the case of high wind speed, the accuracy of the load obtained by using the equivalent turbulence obtained based on the wind speed corresponding to the measuring point in the first area and the wind speed corresponding to the measuring point in the second area for load assessment is better. When the wind speed is low, the turbulence calculated based on the wind speed corresponding to the hub height can be used as the equivalent turbulence for load assessment; when the wind speed is high, the equivalent turbulence obtained based on the wind speed corresponding to the measuring point in the first area and the wind speed corresponding to the measuring point in the second area can be used for load assessment. The wind speed can be distinguished by a preset wind speed threshold. The preset wind speed threshold can be determined according to the scenario, demand, experience, etc., and is not limited here. The preset wind speed threshold corresponding to different wind farms may be different. For example, in wind farm A, if the wind speed is greater than or equal to 10 meters per second, the wind speed is considered to be large; in wind farm B, if the wind speed is greater than or equal to 13 meters per second, the wind speed is considered to be large. In the case where the actual wind speed is less than the preset wind speed threshold, the turbulence corresponding to the hub height can be calculated based on the wind speed measured at the hub height, and the turbulence corresponding to the hub height is used as the equivalent turbulence of the impeller surface and used for load evaluation to obtain the load of the wind turbine. In the case where the actual wind speed is less than the preset wind speed threshold, the equivalent turbulence can be obtained based on the wind speed corresponding to the measuring point in the first area and the wind speed corresponding to the measuring point in the second area, and the equivalent turbulence is used as the equivalent turbulence of the impeller surface and used for load evaluation to obtain the load of the wind turbine. The actual wind speed compared with the preset wind speed threshold can be obtained based on the wind speed corresponding to the measuring point. For example, the actual wind speed can be selected as the maximum wind speed from the wind speeds corresponding to the measuring point, or the actual wind speed can be selected as the minimum wind speed from the wind speeds corresponding to the measuring point, or the actual wind speed can be the wind speed corresponding to the hub height, or the actual wind speed can be the average of the wind speeds of all measuring points, etc., which is not limited here.

[0055] In some embodiments, the wind speed corresponding to the measuring point can be measured by a wind measuring device in the wind farm. The load of the wind turbine in the wind farm can also be determined based on the equivalent turbulence, the position information of the wind measuring device and the wind turbine in the wind farm, and the unit information of the wind turbine in the wind farm. Here, the position information of the wind measuring device and the wind turbine in the wind farm includes the position information of the wind measuring device and the position information of the wind turbine. The unit information may include the model of the unit, the operating status information, etc. The operating status information may include but is not limited to the output power, pitch angle, speed, torque and other information of the wind turbine. The equivalent turbulence can be regarded as the equivalent turbulence at the location of the wind measuring device. The equivalent turbulence at the location of the wind turbine can be inferred based on the position information of the wind measuring device and the wind turbine in the wind farm, so that the load of the wind turbine can be determined based on the equivalent turbulence at the location of the wind turbine and the unit information of the wind turbine. A load assessment model can also be pre-established. Its inputs may include equivalent turbulence, the location of wind turbines and wind measuring devices within the wind farm, and unit information for the wind turbines within the wind farm. Its output is the loads on the wind turbines within the wind farm. The load assessment model can be trained using sample data or employ existing software programs, without limitation.

[0056] In some embodiments, the load assessment of a wind turbine can be applied to monitor the load of a wind turbine in a wind farm that has been built. After obtaining the load of the wind turbine using the load assessment method of the wind turbine in the above embodiment, the load of the wind turbine can be compared with the preset safe load range. If the load of the wind turbine exceeds the preset safe load range, the wind turbine is controlled to operate at a reduced load. The preset safe load range can be used to determine whether the load of the wind turbine is safe. Specifically, it can be set according to the scenario, requirements, and experience, and is not limited here. If the load of the wind turbine does not exceed the preset safe load range, it means that the wind turbine is in a safe operating state and the operation of the wind turbine can be left uninterrupted. If the load of the wind turbine exceeds the preset safe load range, it means that the wind turbine is in a risky operating state and the operation of the wind turbine needs to be intervened. The wind turbine is controlled to operate at a reduced load. Specifically, the wind turbine can be controlled to operate at a reduced power and / or the wind turbine can be controlled to increase the pitch angle. Other control means that can reduce the load of the wind turbine are all within the protection scope of the embodiments of this application and are not described in detail here.

[0057] In some embodiments, wind turbine load assessment can be used to design wind turbines for a wind farm that has not yet been completed, i.e., a simulated wind farm. During wind farm construction, equivalent turbulence can be derived based on the wind speed corresponding to a measurement point in the simulated wind farm. The load of the wind turbine at a preset location in the simulated wind farm can be determined based on the equivalent turbulence. If the wind turbine load is the same as the load of the wind turbines in the simulated wind farm, and the wind turbine load does not meet the wind farm safety load condition, the wind turbine design parameters are updated until the wind turbine load determined based on the equivalent turbulence meets the wind farm safety load condition. The wind farm safety load condition includes the condition that the wind turbine load can maintain a safe state for the wind farm. The specific setting can be based on the scenario, requirements, experience, etc., and is not limited here. If the wind turbine load meets the wind farm safety load condition, it means that the wind turbine design parameters meet the wind farm safety requirements. Installing the wind turbine corresponding to the wind turbine design parameters in the wind farm can ensure the safety of the wind farm, and the wind turbine corresponding to the wind turbine design parameters can be introduced into the wind farm. If the load of a wind turbine fails to meet the wind farm's safety load conditions, it indicates that the wind turbine's design parameters do not meet the wind farm's safety requirements. Installing a wind turbine with these design parameters in a wind farm presents a significant safety risk. The wind turbine's design parameters need to be adjusted to ensure they meet the wind farm's safety requirements. The wind turbine, with design parameters that meet the wind farm's safety requirements, can then be introduced into the wind farm. Adjusting the wind turbine's design parameters based on the wind turbine's load and the wind farm's safety load conditions can reduce the deviation between simulated and measured loads during the wind farm and wind turbine development and verification phases, improving verification quality. This can especially help identify potential load safety issues with newly developed wind turbines, optimizing the wind turbine design process and ensuring wind farm safety.

[0058] For ease of understanding, the load assessment process of a wind turbine generator system in an embodiment of the present application is described below with an example. In this example, the wind measuring device is a wind tower. Figure 6 A schematic diagram of an example of a load assessment process for a wind turbine provided in an embodiment of the present application is shown in FIG. Figure 6 As shown, the load assessment process of the wind turbine generator set may include steps a1 to a8.

[0059] In step a1, wind speeds at multiple actual measurement points are measured using a wind tower. The wind speeds measured can be collected and statistically analyzed with a 10-minute data statistical cycle.

[0060] In step a2, determine whether there is an actual measuring point above the wheel hub height. If so, proceed to step a3; if not, proceed to step a5.

[0061] In step a3, determine whether the number of actual measurement points above the hub height is the same as the number of actual measurement points below the hub height. If they are the same, proceed to step a4; if not, proceed to step a6.

[0062] In step a4, the equivalent turbulence is obtained by using the average value of the turbulence at all actual measurement points at the same time.

[0063] In step a5, virtual measuring points above hub height and the wind speeds corresponding to these virtual measuring points are set. The number of virtual measuring points set is equal to the number of actual measuring points below hub height. If an actual measuring point at hub height exists, the wind speed corresponding to the virtual measuring point is set to the same as the wind speed at hub height. If an actual measuring point at hub height does not exist, the wind speed corresponding to the virtual measuring point is set to the same as the wind speed corresponding to the highest actual measuring point.

[0064] In step a6, virtual measuring points and the corresponding turbulence are set at locations above hub height where actual measuring points are missing. If there are no actual measuring points above the virtual measuring points, the wind speed corresponding to the virtual measuring points is set to be the same as the turbulence corresponding to the highest actual measuring point. After the virtual measuring points are set, the number of measuring points above hub height is the same as the number of measuring points below hub height, including both actual and virtual measuring points.

[0065] In step a7, the equivalent turbulence is obtained by using the average value of the turbulence at all measuring points at the same time.

[0066] In step a8, the load of the wind turbine generator system is obtained according to the equivalent turbulence.

[0067] The specific contents of the above steps a1 to a8 can be found in the relevant descriptions in the above embodiments, which will not be repeated here.

[0068] The present application also provides a load assessment device for a wind turbine generator set. Figure 7 A schematic diagram of the structure of a load assessment device for a wind turbine generator system according to an embodiment of the present application is shown in FIG. Figure 7 As shown, the load evaluation device 200 of the wind turbine generator system may include a wind speed acquisition module 201 , an equivalent turbulence determination module 202 and a load determination module 203 .

[0069] The wind speed acquisition module 201 can be used to obtain the wind speed corresponding to at least one measuring point in the first area and the wind speed corresponding to at least one measuring point in the second area. The first area includes the area above the hub height in the height direction, and the second area includes the area below the hub height in the height direction. The heights of different measuring points are different.

[0070] The equivalent turbulence determination module 202 may be configured to obtain equivalent turbulence based on the wind speed corresponding to the measurement point in the first region and the wind speed corresponding to the measurement point in the second region.

[0071] The load determination module 203 may be used to determine the load of the wind turbine generator system according to the equivalent turbulence.

[0072] In some embodiments, the measuring points include actual measuring points, or the measuring points include actual measuring points and virtual measuring points. When the number of actual measuring points in the first region is different from the number of actual measuring points in the second region, the measuring points in the first target region having the fewer actual measuring points include the actual measuring points and virtual measuring points in the first target region, and the turbulence corresponding to the virtual measuring points is obtained based on the turbulence corresponding to the actual measuring points in the first target region or the turbulence corresponding to the hub height. The first target region is one of the first region and the second region.

[0073] In some embodiments, the load assessment device 200 of the wind turbine generator system may further include a virtual measurement point setting module. The virtual measurement point setting module may be configured to: search, in a first target region, at a hub height, for an actual measurement point that is opposite or approximately opposite to an actual measurement point in a second target region, where the second target region is the other of the first region and the second region; if the first target region lacks an actual measurement point that is opposite or approximately opposite to the actual measurement point in the second target region, set a virtual measurement point at a position opposite or approximately opposite to the actual measurement point in the second target region; and determine the turbulence corresponding to the virtual measurement point based on the turbulence corresponding to the actual measurement point adjacent to the set virtual measurement point or the turbulence corresponding to the hub height.

[0074] In some embodiments, if the number of actual measuring points in the first target area is 0, the turbulence corresponding to the virtual measuring point in the first target area is the same as the turbulence corresponding to the hub height, the turbulence corresponding to the highest actual measuring point in the second target area, or the turbulence corresponding to the lowest actual measuring point in the second target area; if the height of the virtual measuring point in the first area is higher than the height of any actual measuring point in the first area, the turbulence corresponding to the virtual measuring point in the first area is the same as the turbulence corresponding to the highest actual measuring point in the first area; if the height of the virtual measuring point in the second area is lower than the height of any actual measuring point in the second area, the turbulence corresponding to the virtual measuring point in the second area is the same as the turbulence corresponding to the lowest actual measuring point in the second area.

[0075] In some embodiments, in the height direction, the measuring points in the first area and the measuring points in the second area are arranged symmetrically or approximately symmetrically with the hub height as the symmetry axis.

[0076] In some embodiments, the equivalent turbulence determination module 202 can be specifically used to: obtain the turbulence corresponding to the measuring point in the first area based on the wind speed corresponding to the measuring point in the first area; obtain the turbulence corresponding to the measuring point in the second area based on the wind speed corresponding to the measuring point in the second area; use a weighted algorithm to process the turbulence corresponding to the measuring point in the first area and the turbulence corresponding to the measuring point in the second area to obtain equivalent turbulence.

[0077] In some embodiments, the wind speed acquisition module 201 may also be used to: acquire the wind speed corresponding to the hub height.

[0078] The equivalent turbulence determination module 202 may be specifically configured to obtain equivalent turbulence according to the wind speed corresponding to the hub height, the wind speed corresponding to the height of the measuring point in the first region, and the wind speed corresponding to the height of the measuring point in the second region.

[0079] In some embodiments, the wind speed corresponding to the measurement point is measured by a wind measuring device in the wind farm. The load determination module 203 can also be used to determine the load of the wind turbines in the wind farm based on the equivalent turbulence, the location information of the wind measuring device and the wind turbines in the wind farm, and the unit information of the wind turbines in the wind farm.

[0080] In some embodiments, the load assessment device 200 for a wind turbine generator system may further include a control module and / or a parameter updating module.

[0081] The control module can be used to: if the load of the wind turbine generator set exceeds the preset safe load range, control the wind turbine generator set to operate at a reduced load.

[0082] The parameter update module can be used to: when the load of the wind turbine group is the load of the wind turbine group in the simulated wind farm, if the load of the wind turbine group does not meet the wind farm safety load condition, then update the unit design parameters of the wind turbine group until the load of the wind turbine group determined according to the equivalent turbulence meets the wind farm safety load condition.

[0083] It should be noted that the load assessment device 200 of the wind turbine is a device corresponding to the above-mentioned load assessment method of the wind turbine. All implementation methods in the above-mentioned method embodiments are applicable to the embodiments of the device and can achieve the same technical effects.

[0084] The present application also provides a load assessment device for a wind turbine generator set. Figure 8 A schematic diagram of a load evaluation structure for a wind turbine generator system according to an embodiment of the present application is shown in FIG. Figure 8 As shown, the load assessment device 300 for a wind turbine generator system includes a memory 301 , a processor 302 , and a computer program stored in the memory 301 and executable on the processor 302 .

[0085] In some examples, the processor 302 may include a central processing unit (CPU), or an application-specific integrated circuit (ASIC), or may be configured to implement one or more integrated circuits of the embodiments of the present application.

[0086] The memory 301 may include a read-only memory (ROM), a random access memory (RAM), a magnetic disk storage medium device, an optical storage medium device, a flash memory device, an electrical, optical or other physical / tangible memory storage device. Therefore, generally, the memory includes one or more tangible (non-transitory) computer-readable storage media (e.g., a memory device) encoded with software including computer-executable instructions, and when the software is executed (e.g., by one or more processors), it is operable to perform the operations described with reference to the load assessment method for a wind turbine according to an embodiment of the present application.

[0087] The processor 302 reads the executable program code stored in the memory 301 to run a computer program corresponding to the executable program code, so as to implement the load assessment method for the wind turbine generator system in the above embodiment.

[0088] In some examples, the load assessment device 300 for a wind turbine generator system may further include a communication interface 303 and a bus 304. Figure 8 As shown, the memory 301 , the processor 302 , and the communication interface 303 are connected via a bus 304 and communicate with each other.

[0089] The communication interface 303 is mainly used to implement communication between the modules, devices, units and / or equipment in the embodiment of the present application. Input devices and / or output devices can also be connected through the communication interface 303.

[0090] The bus 304 includes hardware, software, or both, and couples the components of the wind turbine load assessment device 300 to each other. By way of example and not limitation, the bus 304 may include an Accelerated Graphics Port (AGP) or other graphics bus, an Enhanced Industry Standard Architecture (EISA) bus, a Front Side Bus (FSB), a HyperTransport (HT) interconnect, an Industry Standard Architecture (ISA) bus, an InfiniBand interconnect, a Low Pin Count (LPC) bus, a memory bus, a Micro Channel Architecture (MCA) bus, a Peripheral Component Interconnect (PCI) bus, a PCI-Express (PCI-E) bus, a Serial Advanced Technology Attachment (SATA) bus, a Video Electronics Standards Association Local Bus (VLB) bus, or other suitable buses, or a combination of two or more of these. Where appropriate, the bus 304 may include one or more buses. Although embodiments herein describe and illustrate a particular bus, this application contemplates any suitable bus or interconnect.

[0091] The present application also provides a computer-readable storage medium having computer program instructions stored thereon. When the computer program instructions are executed by a processor, the load assessment method for a wind turbine generator set in the above-mentioned embodiment can be implemented, and the same technical effect can be achieved. To avoid repetition, the above-mentioned computer-readable storage medium may include a non-transitory computer-readable storage medium, such as a read-only memory (ROM), a random access memory (RAM), a magnetic disk, or an optical disk, etc., which is not limited here.

[0092] The present application also provides a computer program product, which may include a computer program. When the computer program is executed by a processor, it implements the load assessment method for the wind turbine in the above embodiment and can achieve the same technical effect. To avoid repetition, it will not be described here.

[0093] It should be understood that the various embodiments in this specification are described in a progressive manner, and the same or similar parts between the various embodiments can be referred to each other, and each embodiment focuses on the differences from other embodiments. For device embodiments, equipment embodiments, and computer-readable storage medium embodiments, the relevant parts can be referred to the description part of the method embodiment. This application is not limited to the specific steps and structures described above and shown in the figures. Those skilled in the art can make various changes, modifications and additions, or change the order between the steps after understanding the spirit of this application. In addition, for the sake of brevity, a detailed description of known method technologies is omitted here.

[0094] Aspects of the present application have been described above with reference to the flowcharts and / or block diagrams of the methods, devices (systems) and computer program products according to the embodiments of the present application. It should be understood that each box in the flowchart and / or block diagram and the combination of each box in the flowchart and / or block diagram can be implemented by computer program instructions. These computer program instructions can be provided to the processor of a general-purpose computer, a special-purpose computer or other programmable data processing device to produce a machine so that these instructions executed via the processor of the computer or other programmable data processing device enable the implementation of the function / action specified in one or more boxes of the flowchart and / or block diagram. This processor can be, but is not limited to, a general-purpose processor, a special-purpose processor, a special application processor or a field programmable logic circuit. It is also understood that each box in the block diagram and / or the flowchart and the combination of the boxes in the block diagram and / or the flowchart can also be implemented by the dedicated hardware that performs the specified function or action, or can be implemented by the combination of dedicated hardware and computer instructions.

[0095] Those skilled in the art should understand that the above embodiments are illustrative rather than restrictive. Different technical features appearing in different embodiments can be combined to achieve beneficial effects. Based on a study of the drawings, the specification and the claims, those skilled in the art should be able to understand and implement other variations of the disclosed embodiments. In the claims, the term "comprising" does not exclude other devices or steps; the quantifier "one" does not exclude a plurality; the terms "first" and "second" are used to identify names rather than to indicate any specific order. Any figure marks in the claims should not be understood as limiting the scope of protection. The functions of multiple parts appearing in the claims can be implemented by a separate hardware or software module. The fact that certain technical features appear in different dependent claims does not mean that these technical features cannot be combined to achieve beneficial effects.

Claims

1. A method for evaluating the load of a wind turbine generator system, characterized in that: include: Obtaining wind speed corresponding to at least one measuring point in a first area and wind speed corresponding to at least one measuring point in a second area, where the first area includes an area above the hub height in the height direction, and the second area includes an area below the hub height in the height direction, and different measuring points have different heights; Obtaining equivalent turbulence based on wind speeds corresponding to measuring points in the first region and wind speeds corresponding to measuring points in the second region; The load of the wind turbine generator set is determined according to the equivalent turbulence.

2. The method according to claim 1, characterized in that The measuring points include actual measuring points, or the measuring points include actual measuring points and virtual measuring points; When the number of actual measuring points in the first area is different from the number of actual measuring points in the second area, the measuring points in the first target area with the smaller number of actual measuring points include the actual measuring points and virtual measuring points in the first target area, and the turbulence corresponding to the virtual measuring points is obtained based on the turbulence corresponding to the actual measuring points in the first target area or the turbulence corresponding to the hub height. The first target area is one of the first area and the second area.

3. The method according to claim 2, characterized in that Also includes: Searching, in the first target area, for an actual measurement point that is opposite or approximately opposite to an actual measurement point in a second target area based on the wheel hub height, the second target area being the other of the first area and the second area; If the first target area lacks an actual measuring point that is opposite or approximately opposite to the actual measuring point in the second target area, a virtual measuring point is set in the second target area at a position that is opposite or approximately opposite to the actual measuring point, and the turbulence corresponding to the set virtual measuring point is determined based on the turbulence corresponding to the actual measuring point adjacent to the set virtual measuring point or the turbulence corresponding to the hub height.

4. The method according to claim 1, wherein If the height of the virtual measuring point in the first area is higher than the height of any actual measuring point in the first area, the turbulence corresponding to the virtual measuring point in the first area is the same as the turbulence corresponding to the highest actual measuring point in the first area; If the height of the virtual measuring point in the second area is lower than the height of any actual measuring point in the second area, the turbulence corresponding to the virtual measuring point in the second area is the same as the turbulence corresponding to the lowest actual measuring point in the second area.

5. The method according to claim 1, characterized in that In the height direction, the measuring points in the first area and the measuring points in the second area are symmetrically arranged or approximately symmetrically arranged with the hub height as the symmetry axis.

6. The method according to claim 1, characterized in that Obtaining equivalent turbulence based on the wind speed corresponding to the height of the measuring point in the first area and the wind speed corresponding to the height of the measuring point in the second area includes: Obtaining turbulence corresponding to the measuring point in the first area according to the wind speed corresponding to the measuring point in the first area; Obtaining turbulence corresponding to the measuring point in the second area according to the wind speed corresponding to the measuring point in the second area; The turbulence corresponding to the measuring points in the first region and the turbulence corresponding to the measuring points in the second region are processed using a weighted algorithm to obtain the equivalent turbulence.

7. The method according to claim 1, characterized in that Also includes: Obtaining the wind speed corresponding to the hub height; Obtaining equivalent turbulence based on the wind speed corresponding to the height of the measuring point in the first area and the wind speed corresponding to the height of the measuring point in the second area includes: The equivalent turbulence is obtained according to the wind speed corresponding to the hub height, the wind speed corresponding to the height of the measuring point in the first area, and the wind speed corresponding to the height of the measuring point in the second area.

8. The method according to claim 1, characterized in that The wind speed corresponding to the measuring point is measured by the wind measuring device in the wind farm; The method further comprises: The load of the wind turbine in the wind farm is determined according to the equivalent turbulence, the position information of the wind measuring device and the wind turbine in the wind farm, and the turbine information of the wind turbine in the wind farm.

9. The method according to claim 1, characterized in that Also includes: If the load of the wind turbine generator set exceeds a preset safe load range, controlling the wind turbine generator set to operate at a reduced load; and / or, When the load of the wind turbine generator set is the load of the wind turbine generator set in the simulated wind farm, if the load of the wind turbine generator set does not meet the wind farm safety load condition, the unit design parameters of the wind turbine generator set are updated until the load of the wind turbine generator set determined according to the equivalent turbulence meets the wind farm safety load condition.

10. A load assessment device for a wind turbine generator system, characterized in that: include: a processor and a memory storing computer program instructions; When the processor executes the computer program instructions, the load assessment method for a wind turbine generator system according to any one of claims 1 to 9 is implemented.

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