Load evaluation method and apparatus for a wind turbine generator

Abstract

The application discloses a kind of load evaluation method and equipment of wind turbine, belong to wind power technical field.The method includes: obtaining the wind speed corresponding to at least one measuring point in first area and the wind speed corresponding to at least one measuring point in second area, first area includes the area above hub height in height direction, second area includes the area below hub height in height direction, the height of different measuring points is different;Equivalent turbulence is obtained based on the wind speed corresponding to measuring point in first area and the wind speed corresponding to measuring point in second area;The load of wind turbine is determined according to equivalent turbulence.According to the embodiment of the application, the accuracy of load evaluation can be improved.

Description

Technical Field

[0001] This application belongs to the field of wind power technology, and in particular relates to a load assessment method and equipment for wind turbine generators. Background Technology

[0002] The load on a wind turbine refers to the forces and moments acting on its various components. These loads primarily originate from wind power, gravity, inertial forces, and various dynamic effects during operation. Currently, the turbulence at the turbine hub is used as the load input. However, as wind turbines become increasingly larger, the turbulence distribution on the rotor surface no longer satisfies the assumption of spatial uniformity. This leads to a significant deviation between the load obtained from the hub-center turbulence and the actual load, reducing the accuracy of wind turbine load assessment. Summary of the Invention

[0003] This application provides a method and device for load assessment of wind turbine generators, which can improve the accuracy of load assessment.

[0004] In a first aspect, embodiments of this application provide a method for evaluating the load of a wind turbine, comprising: obtaining the wind speed corresponding to at least one measuring point in a first region and the wind speed corresponding to at least one measuring point in a second region, wherein the first region includes a region above the hub height in the height direction and the second region includes a region 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 points in the first region and the wind speed corresponding to the measuring points in the second region; and determining the load of the wind turbine based on the equivalent turbulence.

[0005] In some possible embodiments, the measuring points include actual measuring points, or the measuring points include both 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, which has fewer actual measuring points, include both 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, wherein the first target region is one of the first region and the second region.

[0006] In some possible embodiments, the method further includes: finding an actual measuring point in a first target region that is opposite or approximately opposite to an actual measuring point in a second target region, wherein the second target region is the other of the first and second regions; if there is no actual measuring point in the first target region that is opposite or approximately opposite to an actual measuring point in the second target region, setting a virtual measuring point in the second target region at a position opposite or approximately opposite to an 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 a virtual measuring point in the first region is higher than the height of any actual measuring point in the first region, then the turbulence corresponding to the virtual measuring point in the first region is the same as the turbulence corresponding to the highest actual measuring point in the first region; if the height of a virtual measuring point in the second region is lower than the height of any actual measuring point in the second region, then the turbulence corresponding to the virtual measuring point in the second region is the same as the turbulence corresponding to the lowest actual measuring point in the second region.

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

[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 region and the wind speed corresponding to the height of the measuring point in the second region. This includes: obtaining the turbulence corresponding to the measuring point in the first region based on the wind speed corresponding to the measuring point in the first region; obtaining the turbulence corresponding to the measuring point in the second region based on the wind speed corresponding to the measuring point in the second region; and processing the turbulence corresponding to the measuring point in the first region and the turbulence corresponding to the measuring point in the second region using a weighted algorithm to obtain equivalent turbulence.

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

[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 further includes: determining the load of the wind turbine in the wind farm based on the equivalent turbulence, the location 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.

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

[0013] Secondly, embodiments of this application provide a load assessment device for a wind turbine, comprising: a processor and a memory storing computer program instructions; the processor executes the computer program instructions to implement the load assessment method for the wind turbine of the first aspect.

[0014] This application provides a method and apparatus for load assessment of wind turbine generators. It acquires the wind speeds at measurement points in the upper and lower regions of the hub height, and combines these wind speeds to obtain the equivalent turbulence across the entire impeller surface. Since wind speeds vary at different heights on the impeller surface, the combined wind speeds in the upper and lower regions of the hub height reflect the overall wind speed situation on the impeller surface. Turbulence is the standard deviation of wind speed; correspondingly, the turbulence at different heights on the impeller surface also differs. The equivalent turbulence obtained based on the wind speeds at multiple measurement points in the upper and lower regions of the hub height more accurately reflects the overall turbulence situation on the impeller surface. Using equivalent turbulence instead of single-point turbulence at the hub center for load assessment reduces the influence of turbulence inhomogeneity within the impeller surface, thereby improving the accuracy of load assessment. Attached Figure Description

[0015] To more clearly illustrate the technical solutions of the embodiments of this application, the accompanying drawings used in the embodiments of this application will be briefly introduced below. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0016] Figure 1 A flowchart illustrating a load assessment method for a wind turbine provided in an embodiment of this application;

[0017] Figure 2 This is a schematic diagram of turbulence and equivalent turbulence at multiple actual measuring points in Example 1 of the embodiments of this application;

[0018] Figure 3 This is a comparative diagram showing the loads obtained by evaluating the loads in two different ways according to Example 1 of this application.

[0019] Figure 4 This is a schematic diagram of turbulence and equivalent turbulence at multiple actual measurement points in Example 2 of the embodiments of this application;

[0020] Figure 5 This is a comparative diagram showing the loads obtained by evaluating the loads in two different ways according to Example 1 of this application.

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

[0022] Figure 7 This is a schematic diagram of the structure of a load assessment device for a wind turbine provided in an embodiment of this application;

[0023] Figure 8 This is a structural schematic diagram of a wind turbine load assessment provided in an embodiment of this application. Detailed Implementation

[0024] The features and exemplary embodiments of various aspects of this application will be described in detail below. To make the objectives, technical solutions, and advantages of this application clearer, the application will be further described in detail below with reference to the accompanying drawings and specific embodiments. It should be understood that the specific embodiments described herein are only intended to explain this application and not to limit it. For those skilled in the art, this application can be implemented without some of these specific details. The following description of the embodiments is merely to provide a better understanding of this application by illustrating examples.

[0025] The load on a wind turbine refers to the forces and moments acting on its various components. These loads primarily originate from wind power, gravity, inertial forces, and various dynamic effects during operation. Currently, turbulence at the turbine hub is used as the input for load assessment. However, as wind turbines become increasingly larger, the rotor diameter also increases. The turbulence distribution on the rotor surface no longer satisfies the assumption of spatial uniformity, leading to a significant deviation between the load obtained from the hub-center turbulence and the actual load, thus reducing the accuracy of load assessment.

[0026] This application provides a method, device, apparatus, and storage medium for load assessment of wind turbines. It can address the turbulence distribution within the rotor surface that no longer conforms to spatial uniformity by obtaining multiple turbulences corresponding to multiple corresponding heights based on the wind speeds at multiple measurement points. The equivalent turbulence obtained from these multiple corresponding height turbulences is then used to replace the single-point turbulence at the hub center height for load assessment, thereby reducing the impact of turbulence non-uniformity within the rotor surface on load assessment and improving the accuracy of load assessment.

[0027] The following describes the load assessment method, equipment, apparatus, and storage medium for the wind turbine provided in this application.

[0028] This application provides a load assessment method for wind turbines, which can be used in scenarios where load assessment of wind turbines in wind farms is performed. This load assessment method for wind turbines can be executed by load assessment devices, equipment, systems, etc., and is not limited thereto. Figure 1 A flowchart of a load assessment method for a wind turbine provided in an embodiment of this application is shown below. Figure 1 As shown, the load assessment method for the wind turbine may include steps S101 to S103.

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

[0030] The first region includes the area above the hub height in the vertical direction. The second region includes the area below the hub height in the vertical direction. Here, the vertical direction refers to the height of the wind turbine. Hub height can refer to the height of the hub center. At least one measuring point is set in the first region, and at least one measuring point is set in the second region. The heights of the measuring points are different. For example, if the hub height is 100 meters (i.e., the height of the hub center is 100 meters), and the measuring points include those at 30 meters, 50 meters, 80 meters, 120 meters, and 150 meters, then the area above 100 meters is the first region, and the area below 100 meters is the second region. The measuring points in the first region include those at 120 meters and 150 meters, while the measuring points in the second region include those at 30 meters, 50 meters, and 80 meters. The wind speed at a given measurement point can be obtained using a wind measuring device, which may include, but is not limited to, wind measuring towers, wind measuring radars, etc. Any device capable of measuring wind speed at different heights is within the protection scope of this application's embodiments. The number and arrangement of the wind measuring devices are not limited here; for example, multiple wind turbines can share the same wind measuring device, or each wind turbine can have its own dedicated wind measuring device. For each measurement point, the wind speed at that point can be collected at various times within a preset time period, and the average wind speed at that point within the preset time period is taken as the wind speed corresponding to that measurement point. The preset time period can be determined based on the scenario, requirements, experience, etc., and is not limited here; for example, the preset time period can be 10 minutes. It should be noted that wind speeds at different measurement points need to be collected at the same time.

[0031] In some examples, the measuring points may include actual measuring points. Actual measuring points are real, existing measuring points, determined by the capabilities of the anemometer. For example, the measuring points set by the anemometer itself are actual measuring points, and the number of actual measuring points matches the number set by the anemometer. The wind speed corresponding to the actual measuring point can be directly measured by the anemometer. In other examples, the measuring points may include both actual and virtual measuring points. Virtual measuring points are non-real, meaning the anemometer does not have a real measuring point at the corresponding height of the virtual measuring point. The wind speed corresponding to the virtual measuring point is not directly measured by the anemometer, 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 points meet the preset load assessment requirements, only the actual measuring points need to be considered, the wind speed corresponding to the actual measuring points can be obtained, and subsequent processes can be executed based on the wind speed corresponding to the actual measuring points. In some cases, if the actual measuring points do not meet the preset load assessment requirements, it is necessary to add virtual measuring points to obtain the wind speeds corresponding to both the actual and virtual measuring points. Subsequent procedures are then executed based on these wind speeds. It should be noted that after adding virtual measuring points, the turbulence corresponding to the virtual measuring points can also be obtained from the turbulence calculated based on the wind speeds corresponding to the actual measuring points.

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

[0033] Turbulence at a given measurement point can be calculated based on the wind speed at that point. The turbulence at a single measurement point can be represented by the standard deviation of the wind speed at that point. The turbulence at each measurement point can be calculated first based on the wind speed at each point, and then the equivalent turbulence can be calculated by combining the turbulence at all measurement points. The equivalent turbulence can be the equivalent turbulence on the rotor surface used for load assessment of wind turbines. In some examples, under the same conditions, the higher the measurement point, the smaller the turbulence at that point; conversely, the lower the measurement point, the larger the turbulence at that point. The equivalent turbulence is greater than the turbulence calculated based on the wind speed at the highest measurement point in the first region, and less than the turbulence calculated based on the wind speed at the lowest measurement point in the second region. Compared to using the turbulence at the hub height to represent the turbulence on the rotor surface, the equivalent turbulence provides a more accurate representation of the turbulence on the rotor surface.

[0034] In some examples, the wind speed corresponding to the hub height can also be obtained, with the hub center also considered as a measuring point. Based on the wind speed corresponding to the hub height, the wind speed corresponding to the height of the measuring points in the first region, and the wind speed corresponding to the height of the measuring points in the second region, the equivalent turbulence is obtained. Specifically, 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 height of the measuring points in the first region can be obtained based on the wind speed corresponding to the height of the measuring points in the first region; the turbulence corresponding to the height of the measuring points in the second region can be obtained based on the wind speed corresponding to the height of the measuring points in the second region; and 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 region, and the turbulence corresponding to the height of each measuring point in the second region.

[0035] In some examples, the turbulence corresponding to a measurement point can be calculated based on the wind speed at that point. A weighted algorithm is then used to process the turbulence at each measurement point to obtain equivalent turbulence. For instance, if the measurement points include points in a first region and points in a second region, the turbulence corresponding to the measurement points in the first region can be obtained based on the wind speed at those points; the turbulence corresponding to the measurement points in the second region can be obtained based on the wind speed at those points; and a weighted algorithm is used to process the turbulence at the measurement points in both regions to obtain equivalent turbulence. As another example, if the measurement points include the hub center, points in the first region, and points in the second region, the turbulence corresponding to the hub height can be obtained based on the wind speed at that hub height; the turbulence corresponding to the measurement points in the first region can be obtained based on the wind speed at those points; and the turbulence corresponding to the measurement points in the second region can be obtained based on the wind speed at that hub height; a weighted algorithm is used to process the turbulence at the hub height, the turbulence at the measurement points in the first region, and the turbulence at the measurement points in the second region to obtain equivalent turbulence. In the weighted algorithm, the weight coefficients of the turbulence corresponding to each measurement point can be the same, that is, the equivalent turbulence is the average value of the turbulence corresponding to each measurement point. The weight coefficients of the turbulence corresponding to each measurement point can also be different, which can be set according to specific scenarios, requirements, experience, etc., and are not limited here.

[0036] In other examples, an equivalent turbulence processing model can be trained in advance using the turbulence corresponding to measuring points at different heights in historical data and the equivalent turbulence that can meet the accuracy requirements of load assessment. The turbulence corresponding to the measuring points is calculated based on the wind speeds obtained in this study. The turbulence corresponding to each measuring point is then 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 embodiments may include measuring points in the first region and measuring points in the second region. Alternatively, the measuring points may include the hub center, measuring points in the first region, and measuring points in the second region.

[0038] In step S103, the load on the wind turbine is determined based on the equivalent turbulence.

[0039] There is a physical correlation between equivalent turbulence and the load on a wind turbine. The load on a wind turbine can be determined based on the equivalent turbulence and this physical correlation. In some examples, if multiple wind turbines share a single wind measuring device, the load on each wind turbine can be determined based on the equivalent turbulence, the turbine 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 has its own corresponding wind measuring device, the load on each wind turbine can be determined based on the equivalent turbulence, the turbine information of that 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 located on the wind turbine; the load on the wind turbine can be determined based on the equivalent turbulence, the location information of the wind turbine, and the turbine information of the wind turbine. In some examples, the wind measuring device may be at a certain distance from the wind turbine; the load on the wind turbine can be determined based on the equivalent turbulence, the turbine information of the wind turbine, and the positional relationship between the wind turbine and the wind measuring device.

[0040] In this embodiment, the wind speeds at measurement points in the upper and lower regions of the hub height are obtained, and the equivalent turbulence of the entire impeller surface is obtained by combining the wind speeds at these two regions. Since the wind speeds differ at different heights on the impeller surface, the combined wind speeds in the upper and lower regions of the hub height reflect the overall wind speed situation on the impeller surface. Turbulence is the standard deviation of wind speed; correspondingly, the turbulence at different heights on the impeller surface also differs. The equivalent turbulence obtained based on the wind speeds at multiple measurement points in the upper and lower regions of the hub height more accurately reflects the overall turbulence situation on the impeller surface. Using equivalent turbulence instead of single-point turbulence at the hub center for load assessment reduces the influence of turbulence inhomogeneity within the impeller surface, thereby improving the accuracy of load assessment. Moreover, the wind turbine load assessment method in this embodiment does not require additional simulation of wind parameters within the impeller surface, making it simpler and easier to execute.

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

[0042] If the number of actual measuring points in the first region is the same as the number of actual measuring points in the second region, virtual measuring points are not required. That is, when the number of actual measuring points in the first region is the same as the number of actual measuring points in the second region, the measuring points in the first region include the actual measuring points in the first region, and the measuring points in the second region include the actual measuring points in the second region. Correspondingly, equivalent turbulence can be obtained based on the wind speeds corresponding to the actual measuring points in the first region and the wind speeds corresponding to the actual measuring points in the second region.

[0043] If the number of actual measuring points in the first region differs from that in the second region, virtual measuring points need to be set up in regions with fewer actual measuring points to ensure that the number of measuring points in the first region matches that in the second region. That is, when the number of actual measuring points in the first region differs from that in the second region, the measuring points in the first target region with fewer actual measuring points include both actual and virtual measuring points, while the measuring points in the second target region with more actual measuring points include only the actual measuring points in the second target region. The first target region is one of the first and second regions, and the second target region is the other. The first target region is the one with fewer actual measuring points in the first and second regions, and the second target region is the one with more actual measuring points in the first and second regions. The turbulence corresponding to the virtual measuring points is obtained based on the wind speed or hub height corresponding to the actual measuring points in the first target region. Further, the turbulence corresponding to the virtual measuring points can be determined based on the turbulence corresponding to the adjacent actual measuring points and the positional relationship between the virtual and actual measuring points; alternatively, the turbulence corresponding to the virtual measuring points can be obtained based on the turbulence corresponding to the hub height. Since the turbulence at the measuring point is 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 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, virtual measuring points can be set in the first target area with the goal of making measuring points in the first target area relative to or approximately relative to measuring points in the second target area. Specifically, the hub height can be used to find actual measuring points in the first target area that are relative to or approximately relative to actual measuring points in the second target area. If there are no actual measuring points in the first target area that are relative to or approximately relative to actual measuring points in the second target area, virtual measuring points are set at positions in the second target area that are relative to or approximately relative to actual measuring points. 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. "Relative to measuring points in the first target area and measuring points in the second target area" means that a first distance and a second distance are equal. The first distance is the distance between the height of the measuring point in the first target area and the hub height, and the second distance is the distance between the height of the measuring point in the second target area and the hub height. The measurement points in the first target area and the measurement points in the second target area are approximately opposite each other, meaning that the difference between the first distance and the second distance is within a preset difference range. This 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 it is not limited to this example.

[0045] In some examples, if the number of actual measuring points in the first target region is 0, then the turbulence corresponding to the virtual measuring points in the first target region is the same as the turbulence corresponding to the hub height, the turbulence corresponding to the highest actual measuring point in the second target region, or the turbulence corresponding to the lowest actual measuring point in the second target region. A number of actual measuring points in the first target region being 0 indicates that there are no actual measuring points in the first target region; that is, all measuring points in the first target region are virtual measuring points. If there are actual measuring points for the hub height, the turbulence corresponding to the hub height can be determined as the turbulence corresponding to the height of each virtual measuring point in the first target region. For example, if the hub height is 100 meters, the first target area is the first region (with no actual measuring points), and the second region includes two actual measuring points at heights of 50 meters and 80 meters respectively, virtual measuring points can be set at heights of 120 meters and 150 meters in the first region, using the hub height (100 meters) as a baseline. The turbulence corresponding to the virtual measuring point at 120 meters and the turbulence corresponding to the virtual measuring point at 150 meters can be set as the turbulence corresponding to the hub height. If there are no actual measuring points at the hub height, and the first target area is the first region, the turbulence corresponding to the highest actual measuring point in the second region can be determined as the turbulence corresponding to the height of each virtual measuring point in the first target area. If there are no actual measuring points at the hub height, and the first target area is the second region, the turbulence corresponding to the lowest actual measuring point in the first region 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 a virtual measuring point in the first region is higher than the height of any actual measuring point in the first region, then the turbulence corresponding to the virtual measuring point in the first region is the same as the turbulence corresponding to the highest actual measuring point in the first region. If the first region lacks actual measuring points that are symmetrical or approximately symmetrical to the actual measuring points in the second region, and the position of the missing actual measuring point in the first region is higher than any of the actual measuring points in the first region, then a virtual measuring point needs to be set above the highest actual measuring point in the first region. The turbulence corresponding to this virtual measuring point can be taken as the turbulence corresponding to the highest actual measuring point in the first region. For example, if the hub height is 100 meters, the second region includes actual measuring points at heights of 50 meters and 80 meters, and the first region only has actual measuring points at heights of 120 meters, then a virtual measuring point at a height of 150 meters needs to be set, and the turbulence corresponding to the virtual measuring point at 150 meters should be set to be the same as the turbulence corresponding to the actual measuring point at 120 meters.

[0047] In some examples, if the height of a virtual measuring point in the second region is lower than the height of any actual measuring point in the second region, then the turbulence corresponding to the virtual measuring point in the second region is the same as the turbulence corresponding to the lowest actual measuring point in the second region. If the second region lacks actual measuring points that are symmetrical or approximately symmetrical to the actual measuring points in the first region, and the position corresponding to the missing actual measuring point in the second region is lower than all the actual measuring points present in the second region, then a virtual measuring point needs to be set below the lowest actual measuring point in the second region. The turbulence corresponding to this virtual measuring point can be taken as the turbulence corresponding to the lowest actual measuring point in the second region. For example, if the hub height is 100 meters, the second region includes actual measuring points at a height of 80 meters, and the first region includes actual measuring points at heights of 120 meters and 150 meters, then a virtual measuring point at a height of 50 meters needs to be set, and the turbulence corresponding to this virtual measuring point should be set to be the same as the turbulence corresponding to the actual measuring point at a height of 80 meters.

[0048] In some examples, if there are actual measuring points above and below a virtual measuring point in the first target region, the turbulence corresponding to that virtual measuring point can be calculated based on the turbulence corresponding to the adjacent actual measuring points above and below it. Interpolation or fitting algorithms can be used to calculate the turbulence corresponding to that virtual measuring point. Similarly, if there are actual measuring points above and below a virtual measuring point in the first target region, the turbulence corresponding to that virtual measuring point can be calculated based on the wind speeds corresponding to more actual measuring points above and below it. These more actual measuring points include not only the two adjacent actual measuring points but also other actual measuring points. Interpolation or fitting algorithms can be used to calculate the turbulence corresponding to that virtual measuring point.

[0049] In some embodiments, the measuring points in the first region and the measuring points in the second region are arranged symmetrically or approximately symmetrically about the hub height. Approximate symmetrical arrangement of the measuring points in the first region and the second region about the hub height means that the measuring points in the first region and the second region are arranged symmetrically about the hub height 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 all the measuring points in the second region. The first region includes measuring points at heights of 110 meters, 120 meters, and 130 meters, and the second region includes measuring points at heights of 90 meters, 80 meters, and 70 meters. As another example, if the hub height is 100 meters, the measuring points in the first region are approximately symmetrically arranged with all the measuring points in the second region. The first region includes measuring points at heights of 110 meters, 119 meters, and 132 meters, and the second region includes measuring points at heights of 90 meters, 80 meters, and 70 meters. The symmetrical arrangement of the measuring points in the first region and the second region allows the equivalent turbulence obtained from the wind speeds corresponding to the measuring points in the first region and the wind speeds corresponding to the measuring points in the second region to better match the actual turbulence on the impeller surface. In other words, the equivalent turbulence is more accurate, which in turn makes the load of the wind turbine more accurate in the evaluation.

[0050] To facilitate understanding, two examples are provided below to illustrate the effect of the load assessment method for wind turbines in this 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 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 is the height of the tip of the wind turbine blade from the bottom surface when it is at a 180° azimuth angle, i.e., vertically downward. The height of the actual measuring point at the lower blade tip is less than 50 meters. The hub height is also an actual measuring point, and the hub height is greater than 80 meters. Figure 2 This is a schematic diagram of turbulence and equivalent turbulence at multiple actual measuring points in Example 1 of this application's embodiments. Figure 3 This is a comparative diagram showing the loads obtained by evaluating the loads in Example 1 of this application. Figure 3 The load involved is the tower load My of the wind turbine, which is most affected by turbulence. Figure 2 The horizontal axis represents wind speed in meters per second, and the vertical axis represents turbulence in meters per second. Figure 2The lower blade tip turbulence is calculated based on the wind speed at the actual measuring point at the lower blade tip position; the 50-meter height turbulence is calculated based on the wind speed at the actual measuring point at 50 meters; the 80-meter height turbulence is calculated based on the wind speed at the actual measuring point at 80 meters; the hub height turbulence is calculated based on the wind speed at the hub height; and the equivalent turbulence is the equivalent turbulence obtained using the wind turbine load assessment method described in this application. Figure 2 It can be seen that in areas with low 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 high wind speeds, such as wind speeds greater than or equal to 10 m / s, the turbulence corresponding to the higher the actual measuring point is, the lower the turbulence corresponding to the actual measuring point is, and the turbulence corresponding to the lower the actual measuring point is, the higher the turbulence corresponding to the actual measuring point is, and the equivalent turbulence is higher than the turbulence at the hub height. Figure 3 The horizontal axis represents wind speed in meters per second, and the vertical axis represents the ratio of the assessed load to the measured load in percentage. Example 1 illustrates two methods for assessing the load: Method 1 and Method 2. Method 1 uses the turbulence corresponding to the hub height as the equivalent turbulence load assessment method for the impeller surface. Method 2 uses the equivalent turbulence obtained in this embodiment, based on the wind speeds at the measuring points in the first and second regions, as the equivalent turbulence load assessment method for the impeller surface. Figure 3 It can be seen that in areas with low wind speeds, such as wind speeds less than 10 m / s, the ratio of the load obtained by method one to the measured load is not significantly different from the ratio of the load obtained by method two. However, in areas with high wind speeds, such as wind speeds greater than or equal to 10 m / s, the difference between the ratio of the load obtained by method one and the measured load and 100% is relatively larger, while the difference between the ratio of the load obtained by method two and the measured load and 100% is relatively smaller. The deviation between the load obtained by method two, i.e., the load evaluation method for wind turbines in this embodiment, and the measured load is reduced by 2% to 9% under various wind speed conditions. In other words, the deviation between the load obtained by the load evaluation method for wind turbines in this embodiment and the measured load is smaller, and the load obtained by the load evaluation method for wind turbines in this embodiment is closer to the measured load. Therefore, the load obtained by the load evaluation method for wind turbines in this embodiment is more accurate.

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

[0053] Figure 4 This is a schematic diagram of turbulence and equivalent turbulence at multiple actual measuring points in Example 2 of the embodiments of this application. Figure 5 This is a comparative diagram showing the loads obtained by evaluating the loads in Example 1 of this application. Figure 5 The load involved is the tower load My of the wind turbine, which is most affected by turbulence. Figure 4 The horizontal axis represents wind speed in meters per second, and the vertical axis represents turbulence in meters per second. Figure 4 The turbulence at the lower blade tip is calculated based on the wind speed at the measuring point at the lower blade tip position; the turbulence at 50 meters is calculated based on the wind speed at the measuring point at 50 meters; the turbulence at 70 meters is calculated based on the wind speed at the measuring point at 70 meters; the turbulence at 90 meters is calculated based on the wind speed at the measuring point at 90 meters; the turbulence at the hub height is calculated based on the wind speed at the hub height; the equivalent turbulence is the equivalent turbulence obtained using the load assessment method for the wind turbine in this embodiment; the turbulence at 160 meters is calculated based on the wind speed at the measuring point at 160 meters; the turbulence at 180 meters is calculated based on the wind speed at the measuring point at 180 meters; and the turbulence at 200 meters is calculated based on the wind speed at the measuring point at 200 meters. Figure 4 It can be seen that in areas with high wind speeds, such as wind speeds greater than or equal to 13 m / s, the higher the actual measuring point, the lower the turbulence, and the lower the actual measuring point, the higher the turbulence. The equivalent turbulence is higher than the hub height turbulence. Figure 5 The horizontal axis represents wind speed in meters per second, and the vertical axis represents the ratio of the assessed load to the measured load in percentage. Example 2 illustrates two methods for assessing the load: Method 1 and Method 2. Method 1 uses the turbulence corresponding to the hub height as the equivalent turbulence load assessment method for the impeller surface. Method 2 uses the equivalent turbulence obtained in this embodiment, based on the wind speeds at the measuring points in the first and second regions, as the equivalent turbulence load assessment method for the impeller surface. Figure 5It can be seen that in areas with low wind speeds, such as wind speeds less than 13 m / s, the ratio of the load obtained by method one to the measured load is not significantly different from the ratio of the load obtained by method two. However, in areas with high wind speeds, such as wind speeds greater than or equal to 13 m / s, the difference between the ratio of the load obtained by method one and the measured load and 100% is relatively larger, while the difference between the ratio of the load obtained by method two and the measured load and 100% is relatively smaller. The deviation between the load obtained by method two, i.e., the load evaluation method for wind turbines in this embodiment, and the measured load is reduced by 2% to 6% under various wind speed conditions. In other words, the deviation between the load obtained by the load evaluation method for wind turbines in this embodiment and the measured load is smaller, and the load obtained by the load evaluation method for wind turbines in this embodiment is closer to the measured load. Therefore, the load obtained by the load evaluation method for wind turbines in this embodiment is more accurate.

[0054] In some embodiments, the load assessment can be determined based on the wind speed corresponding to the measuring point, either by using equivalent turbulence obtained from the wind speeds corresponding to the measuring points in the first and second regions, or by using turbulence calculated based on the wind speed corresponding to the hub height. Since the load assessment obtained from equivalent turbulence based on the wind speeds corresponding to the measuring points in the first and second regions is more accurate when the wind speed is high, 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 low; and when the wind speed is high, the equivalent turbulence obtained from the wind speeds corresponding to the measuring points in the first and second regions can be used for load assessment. Wind speed magnitude can be distinguished by preset wind speed thresholds. These thresholds can be determined based on the scenario, requirements, and experience, and are not limited here. Different wind farms may have different preset wind speed thresholds. For example, in wind farm A, a wind speed greater than or equal to 10 m / s is considered relatively high; in wind farm B, a wind speed greater than or equal to 13 m / s is considered relatively high. When the actual wind speed is less than the preset threshold, the turbulence corresponding to the hub height can be calculated based on the wind speed measured at the hub height. This turbulence is used as the equivalent turbulence on the rotor surface and applied to load assessment to obtain the wind turbine load. Alternatively, when the actual wind speed is less than the preset threshold, equivalent turbulence can be obtained based on the wind speeds at the measuring points in the first and second regions. This equivalent turbulence is used as the equivalent turbulence on the rotor surface and applied to load assessment to obtain the wind turbine load. The actual wind speed compared with the preset wind speed threshold can be obtained from the wind speed corresponding to the measuring point. For example, the actual wind speed can be the maximum wind speed selected from the wind speeds corresponding to the measuring point, or the actual wind speed can be the minimum wind speed selected from the wind speeds corresponding to the measuring point, or the actual wind speed can be the wind speed corresponding to the wheel hub height, or the actual wind speed can be the average of the wind speeds of all measuring points, etc. There are no limitations here.

[0055] In some embodiments, the wind speed corresponding to the measuring point can be measured by an anemometer in the wind farm. The load on the wind turbine in the wind farm can also be determined based on equivalent turbulence, the location information of the anemometer and wind turbine in the wind farm, and the turbine unit information. Here, the location information of the anemometer and wind turbine includes the location information of both the anemometer and the wind turbine. Turbine information may include the turbine model, operating status information, etc., and the operating status information may include, but is not limited to, the wind turbine's output power, pitch angle, speed, torque, etc. The equivalent turbulence can be considered as the equivalent turbulence at the location of the anemometer. The equivalent turbulence at the location of the wind turbine can be inferred from the location information of the anemometer and wind turbine in the wind farm, thereby determining the load on the wind turbine based on the equivalent turbulence at the location of the wind turbine combined with the turbine unit information. Alternatively, a load assessment model can be pre-established. The inputs to the load assessment model may include equivalent turbulence, location information of wind measuring devices and wind turbines in the wind farm, and turbine information of the wind turbines in the wind farm. The output of the load assessment model is the load of the wind turbines in the wind farm. The load assessment model can be trained using sample data or can use existing software programs, etc., and there are no limitations here.

[0056] In some embodiments, wind turbine load assessment can be applied to monitor the load of wind turbines in completed wind farms. After obtaining the wind turbine load using the wind turbine load assessment method in the above embodiments, the wind turbine load can be compared with a preset safe load range. If the wind turbine load exceeds the preset safe load range, the wind turbine is controlled to operate with reduced load. The preset safe load range can be used to determine whether the wind turbine load is safe, and can be set according to the scenario, requirements, and experience, and is not limited here. If the wind turbine load does not exceed the preset safe load range, it means that the wind turbine is in a safe operating state, and no intervention is needed in the operation of the wind turbine. If the wind turbine load exceeds the preset safe load range, it means that the wind turbine is in a risky operating state, and intervention is needed in the operation of the wind turbine to control the wind turbine to operate with reduced load. Specifically, the wind turbine can be controlled to operate with reduced power and / or the wind turbine can be controlled to increase the pitch angle. Other control means that can reduce the wind turbine load are all within the protection scope of the embodiments of this application, and will not be described in detail here.

[0057] In some embodiments, the load assessment of wind turbines can be applied to the design of wind turbines in simulated wind farms that are not yet fully constructed. During the construction of the wind farm, equivalent turbulence can be obtained based on the wind speeds at measuring points in the simulated wind farm, and the load of wind turbines at preset locations in the simulated wind farm can be determined based on this equivalent turbulence. If the load of the wind turbine does not meet the wind farm's safe load conditions when it is the same as that of the wind turbines in the simulated wind farm, the turbine design parameters are updated until the load determined based on the equivalent turbulence meets the wind farm's safe load conditions. The wind farm's safe load conditions include the conditions under which the wind turbine load is sufficient for the wind farm to be in a safe state; these conditions can be set according to the scenario, requirements, experience, etc., and are not limited here. If the wind turbine load meets the wind farm's safe load conditions, it means that the turbine design parameters meet the wind farm's safety requirements. Installing the wind turbine corresponding to these design parameters in the wind farm can ensure the safety of the wind farm, and the wind turbine corresponding to these design parameters can be introduced into the wind farm. If the load on a wind turbine does not meet the safe load conditions of the wind farm, it indicates that the turbine's design parameters do not comply with the wind farm's safety requirements. Installing a wind turbine with these design parameters in the wind farm poses a significant safety risk. Therefore, it is necessary to adjust the turbine's design parameters to meet the wind farm's safety requirements before introducing the turbine into the wind farm. Adjusting the turbine's design parameters based on the load on the wind turbine and the wind farm's safe load conditions can reduce the deviation between simulated and measured loads during the wind farm and turbine development and verification phases, improving verification quality. This is especially important for newly developed wind turbines, as it allows for the early detection of potential load safety issues, optimizes the turbine design process, and ensures the safety of the wind farm.

[0058] For ease of understanding, the following example illustrates the load assessment process of the wind turbine in this application embodiment. In this example, the wind measuring device is a wind measuring tower. Figure 6 This is a schematic diagram illustrating an example of the load assessment process for a wind turbine provided in an embodiment of this application, as shown below. Figure 6 As shown, the load assessment process for this wind turbine may include steps a1 to a8.

[0059] In step a1, wind speeds at multiple actual measuring points are obtained using a wind tower. The measured wind speeds can be collected and statistically analyzed at 10-minute intervals.

[0060] In step a2, determine whether there is an actual measuring point above the wheel hub height. If there is, proceed to step a3; otherwise, proceed to step a5.

[0061] In step a3, determine whether the number of actual measuring points above the wheel hub height is the same as the number of actual measuring points below the wheel hub height. If they are the same, proceed to step a4; if they are different, 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 moment.

[0063] In step a5, virtual measuring points above the wheel hub height and their corresponding wind speeds are set. The number of virtual measuring points is the same as the number of actual measuring points below the wheel hub height. If an actual measuring point exists at the wheel hub height, the wind speed corresponding to the virtual measuring point is set to be the same as the wind speed at the wheel hub height. If no actual measuring point exists at the wheel hub height, the wind speed corresponding to the virtual measuring point is set to be the same as the wind speed corresponding to the highest actual measuring point.

[0064] In step a6, virtual measuring points and their corresponding turbulence are set at locations above the wheel hub height where no actual measuring points are found. If there are no actual measuring points above the virtual measuring points, the wind speed corresponding to the virtual measuring point is set to be the same as the turbulence corresponding to the highest actual measuring point. After setting virtual measuring points, the number of measuring points above the wheel hub height is the same as the number of measuring points below the wheel hub height, and the measuring points include 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 is obtained based on the equivalent turbulence.

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

[0068] This application also provides a load assessment device for wind turbine generators. Figure 7 This is a schematic diagram of the structure of a load assessment device for a wind turbine provided in an embodiment of this application, as shown below. Figure 7 As shown, the load assessment device 200 for the wind turbine 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 acquire the wind speed corresponding to at least one measuring point in the first region and the wind speed corresponding to at least one measuring point in the second region. The first region includes the region above the hub height in the height direction, and the second region includes the region below the hub height in the height direction. The heights of different measuring points are different.

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

[0071] The load determination module 203 can be used to determine the load of the wind turbine based on the equivalent turbulence.

[0072] In some embodiments, the measuring points include actual measuring points, or, the measuring points include both actual measuring points and virtual measuring points; when the number of actual measuring points in the first region differs from the number of actual measuring points in the second region, the measuring points in the first target region, which has fewer actual measuring points, include both 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 for wind turbines may further include a virtual measuring point setting module. The virtual measuring point setting module can be used to: locate, based on the hub height, an actual measuring point in a first target region that is opposite or approximately opposite to an actual measuring point in a second target region, where the second target region is the other of the first and second regions; if the first target region lacks an actual measuring point that is opposite or approximately opposite to an actual measuring point in the second target region, set a virtual measuring point at a position in the second target region that is opposite or approximately opposite to an actual measuring point, and determine the turbulence corresponding to the set virtual measuring point based on the turbulence corresponding to an actual measuring point adjacent to the set virtual measuring point or the turbulence corresponding to the hub height.

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

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

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

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

[0078] The equivalent turbulence determination module 202 can be specifically used to obtain 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 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 measuring point is measured by the wind measuring device in the wind farm. The load determination module 203 can also be used to: determine the load of the wind turbine in the wind farm based on the equivalent turbulence, the location 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.

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

[0081] The control module can be used to control the wind turbine to reduce its load if the load exceeds the preset safe load range.

[0082] The parameter update module can be used to update the wind turbine design parameters when the load of the wind turbine is the same as the load of the wind turbine in the simulated wind farm. If the load of the wind turbine does not meet the safe load conditions of the wind farm, the module will update the wind turbine design parameters until the load of the wind turbine determined according to the equivalent turbulence meets the safe load conditions of the wind farm.

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

[0084] This application also provides a load assessment device for wind turbine generators. Figure 8 A structural schematic diagram of a wind turbine load assessment provided in an embodiment of this application is shown below. Figure 8 As shown, the wind turbine load assessment device 300 includes a memory 301, a processor 302, and a computer program stored in the memory 301 and capable of running on the processor 302.

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

[0086] Memory 301 may include read-only memory (ROM), random access memory (RAM), disk storage media device, optical storage media device, flash memory device, electrical, optical, or other physical / tangible memory storage device. Therefore, typically, memory includes one or more tangible (non-transitory) computer-readable storage media (e.g., memory devices) 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 wind turbine load assessment method according to embodiments of this application.

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

[0088] In some examples, the wind turbine load assessment device 300 may also include a communication interface 303 and a bus 304. For example, Figure 8 As shown, the memory 301, processor 302, and communication interface 303 are connected through bus 304 and complete communication with each other.

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

[0090] Bus 304 includes hardware, software, or both, that couples the components of the wind turbine load assessment device 300 together. For example, and not limitingly, 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 Hyper Transport (HT) interconnect, an Industry Standard Architecture (ISA) bus, an Infinite Bandwidth 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, bus 304 may include one or more buses. Although specific buses are described and illustrated in the embodiments of this application, this application considers any suitable bus or interconnection.

[0091] This application also provides a computer-readable storage medium storing computer program instructions. When these computer program instructions are executed by a processor, they can implement the wind turbine load assessment method described in the above embodiments and achieve the same technical effect. To avoid repetition, further details are omitted here. The aforementioned computer-readable storage medium may include non-transitory computer-readable storage media, such as read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks, etc., and is not limited thereto.

[0092] This 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 evaluation method for wind turbines in the above embodiments and can achieve the same technical effect. To avoid repetition, it will not be described again here.

[0093] It should be clarified 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 mutually. Each embodiment focuses on describing the differences from other embodiments. For the device embodiments, equipment embodiments, and computer-readable storage medium embodiments, the relevant parts can be referred to the description section of the method embodiments. 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 of steps, after understanding the spirit of this application. Furthermore, for the sake of brevity, detailed descriptions of known methods and techniques are omitted here.

[0094] The aspects of this application have been described above with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It should be understood that each block in the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing apparatus to produce a machine such that these instructions, executable via the processor of the computer or other programmable data processing apparatus, enable the implementation of the functions / actions specified in one or more blocks of the flowchart illustrations and / or block diagrams. Such a 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 block in the block diagrams and / or flowcharts, and combinations of blocks in the block diagrams and / or flowcharts, can also be implemented by dedicated hardware performing the specified functions or actions, or can be implemented by a combination of dedicated hardware and computer instructions.

[0095] Those skilled in the art will understand that the above embodiments are exemplary and not restrictive. Different technical features appearing in different embodiments can be combined to achieve beneficial effects. Based on a study of the drawings, specification, and 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 means or steps; the quantifier "a" does not exclude a plurality; the terms "first" and "second" are used to identify names and not to indicate any particular order. No reference numerals in the claims should be construed as limiting the scope of protection. The functionality of multiple parts appearing in the claims can be implemented by a single hardware or software module. The appearance of certain technical features in different dependent claims does not mean that these technical features cannot be combined to achieve beneficial effects.

Claims

1. A load assessment method for wind turbine generators, characterized in that, include: The wind speed corresponding to at least one measuring point in the first region and the wind speed corresponding to at least one measuring point in the second region are obtained. The first region includes the region above the hub height in the height direction, and the second region includes the region below the hub height in the height direction. The heights of different measuring points are different. Based on the wind speeds at the measuring points in the first region and the wind speeds at the measuring points in the second region, equivalent turbulence is obtained. The load on the wind turbine is determined based on the equivalent turbulence. Among them, 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 with fewer actual measuring points include the actual measuring points in the first target region and the virtual measuring points. 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. If the height of the virtual measuring point in the first region is higher than the height of any actual measuring point in the first region, then the turbulence corresponding to the virtual measuring point in the first region is the same as the turbulence corresponding to the highest actual measuring point in the first region. If the height of the virtual measuring point in the second region is lower than the height of any actual measuring point in the second region, then the turbulence corresponding to the virtual measuring point in the second region is the same as the turbulence corresponding to the actual measuring point with the lowest height in the second region.

2. The method according to claim 1, characterized in that, Also includes: Find the actual measuring point in the first target area that is opposite to the actual measuring point in the second target area based on the hub height. The second target area is the other one of the first area and the second area. If there is no actual measuring point in the first target area that is 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 opposite to the actual measuring point. 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.

3. The method according to claim 1, characterized in that, In the height direction, the measuring points in the first region and the measuring points in the second region are arranged symmetrically about the hub height.

4. The method according to claim 1, characterized in that, The equivalent turbulence is obtained based on 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, including: Based on the wind speed at the measuring point in the first region, the turbulence at the measuring point in the first region is obtained; Based on the wind speed at the measuring point in the second region, the turbulence at the measuring point in the second region is obtained; Using a weighted algorithm, the turbulence corresponding to the measurement points in the first region and the turbulence corresponding to the measurement points in the second region are processed to obtain the equivalent turbulence.

5. The method according to claim 1, characterized in that, Also includes: Obtain the wind speed corresponding to the hub height; The equivalent turbulence is obtained based on 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, including: The equivalent turbulence is obtained based on 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.

6. The method according to claim 1, characterized in that, The wind speed at the measuring point is obtained by the wind measuring device in the wind farm. The method further includes: The load of the wind turbine in the wind farm is determined based on the equivalent turbulence, the location 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.

7. The method according to claim 1, characterized in that, Also includes: If the load on the wind turbine exceeds the preset safe load range, the wind turbine will be controlled to operate with reduced load. And / or, If the load of the wind turbine is the same as the load of the wind turbine in the simulated wind farm, and the load of the wind turbine does not meet the safe load conditions of the wind farm, then the turbine design parameters of the wind turbine are updated until the load of the wind turbine determined according to the equivalent turbulence meets the safe load conditions of the wind farm.

8. A load assessment device for wind turbine generators, characterized in that, include: Processor and memory storing computer program instructions; When the processor executes the computer program instructions, it implements the load assessment method for wind turbines as described in any one of claims 1 to 7.

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