CN109946475B - Method and device for determining wind speed - Google Patents
Method and device for determining wind speed Download PDFInfo
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- CN109946475B CN109946475B CN201711392072.5A CN201711392072A CN109946475B CN 109946475 B CN109946475 B CN 109946475B CN 201711392072 A CN201711392072 A CN 201711392072A CN 109946475 B CN109946475 B CN 109946475B
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Abstract
The invention provides a method and a device for determining wind speed, wherein the method comprises the following steps: acquiring an incoming flow wind speed of any wind generating set in a wind power plant; determining a projection area formed by intersecting a wake flow formed by the incoming flow behind a wind wheel of any one of the wind generating sets and a swept plane of a wind wheel of a downstream wind generating set; determining a sweep area formed by a wind rotor of the downstream wind turbine generator set on the sweep plane; determining a wind speed in an overlap region between a projected area formed by the wake intersecting the swept plane and the swept area, and determining the wind speed in the overlap region as a wind speed at the downstream wind turbine generator set. By adopting the method and the device, the wind speed of each wind generating set in the wind power plant can be more accurately evaluated.
Description
Technical Field
The present application relates to the field of wind power generation technologies, and in particular, to a method and an apparatus for determining a wind speed.
Background
With the development of wind power generation technology and the decrease of land wind power plant resources, the development of offshore wind power plants becomes the mainstream trend. However, due to the low turbulence intensity of the offshore environment, the layout space of the wind generating sets in the wind power plant is limited, and the mutual influence of the flow fields among the wind generating sets is particularly serious. This phenomenon of upstream and downstream interaction between wind turbine generators is called wake effect. The wake effect not only has obvious influence on the pneumatic performance of the blades of the wind generating set, but also can directly cause the efficiency of the wind generating set to be greatly reduced, and simultaneously, the blades of the wind generating set generate fatigue effect, thereby reducing the service life of the blades.
Therefore, a method and a device for determining wind speed based on wake effect are urgently needed so as to provide more accurate and reliable data basis for construction and control of a wind power plant.
Disclosure of Invention
The invention aims to provide a method and a device for determining wind speed.
According to an aspect of the invention, there is provided a method of determining wind speed, the method comprising: acquiring an incoming flow wind speed of any wind generating set in a wind power plant; determining a projection area formed by intersecting a wake flow formed by the incoming flow behind a wind wheel of any one of the wind generating sets and a swept plane of a wind wheel of a downstream wind generating set; determining a sweep area formed by a wind rotor of the downstream wind turbine generator set on the sweep plane; determining a wind speed in an overlap region between a projected area formed by the wake intersecting the swept plane and the swept area, and determining the wind speed in the overlap region as a wind speed at the downstream wind turbine generator set.
Preferably, the step of determining a projection area formed by the intersection of the wake and the sweep plane comprises: dividing the wake into a plurality of wake regions; determining each projected area formed by each divided wake area intersecting the sweep plane.
Preferably, the step of determining the wind speed in an overlap region between a projected area formed by the wake intersecting the sweep plane and the sweep area comprises: determining a wind speed in each overlap region between the each projected area and the swept area; determining a wind speed in an overlap region between a projection region formed by the wake intersecting the sweep plane and the sweep region based on a weight that each overlap region between the each projection region and the sweep region has, respectively, with respect to the sweep region and the wind speed in each overlap region between the each projection region and the sweep region.
Preferably, the method further comprises: determining turbulence intensity at the downstream wind generating set according to the wind speed at the downstream wind generating set; correcting the wind speed at the downstream wind power generation unit based on the turbulence intensity at the downstream wind power generation unit until a difference between the wind speed at the downstream wind power generation unit and the corrected wind speed at the downstream wind power generation unit is less than a predetermined threshold; and outputting the corrected wind speed at the downstream wind generating set as the wind speed at the downstream wind generating set.
Preferably, the wake comprises at least one of a near-field region, a far-field region and a mixed region.
According to another aspect of the present invention, there is provided the apparatus for determining wind speed, the apparatus comprising: the wind speed acquisition unit is used for acquiring the incoming wind speed of any wind generating set in the wind power plant; the projection area determining unit is used for determining a projection area formed by intersecting a wake flow formed by the incoming flow behind the wind wheel of any wind generating set and a swept plane of the wind wheel of a downstream wind generating set; a swept area determination unit which determines a swept area formed on the swept plane by a wind rotor of the downstream wind turbine generator set; a first wind speed determination unit that determines a wind speed in an overlap region between a projected area formed by the wake intersecting the sweep plane and the sweep area, and determines the wind speed in the overlap region as a wind speed at the downstream wind turbine generator set.
Preferably, the projection region determining unit includes: a wake flow region dividing unit which divides the wake flow into a plurality of wake flow regions; and the projection area determining subunit determines each projection area formed by intersecting each divided wake area with the sweep plane.
Preferably, the first wind speed determination unit includes: a regional wind speed determination subunit that determines a wind speed in each overlap region between the each projection region and the swept region; an equivalent wind speed determination subunit that determines a wind speed in an overlap region between a projection region formed by the wake intersecting the sweep plane and the sweep region, based on a weight that each overlap region between the projection region and the sweep region has with respect to the sweep region, respectively, and a wind speed in each overlap region between the projection region and the sweep region.
Preferably, the apparatus further comprises: the turbulence intensity determination unit is used for determining the turbulence intensity at the downstream wind generating set according to the wind speed at the downstream wind generating set; a wind speed correction unit correcting a wind speed at the downstream wind turbine generator set based on the turbulence intensity at the downstream wind turbine generator set until a difference between the wind speed at the downstream wind turbine generator set and the corrected wind speed of the downstream wind turbine generator set is less than a predetermined threshold; and the second wind speed determination unit outputs the corrected wind speed at the downstream wind generating set as the wind speed at the downstream wind generating set.
Preferably, the wake comprises at least one of a near-field region, a far-field region and a mixed region.
According to another aspect of the invention, a computer-readable storage medium is provided, having stored thereon a computer program, which, when being executed by a processor, carries out the method of determining a wind speed as set forth above.
According to another aspect of the present invention, there is provided a computer apparatus comprising: a processor; a memory storing a computer program which, when executed by the processor, implements the method of determining wind speed as described above.
The method and the device for determining the wind speed can accurately evaluate the wind speed of each wind generating set in the wind power plant based on the wake effect, so that a more reliable and accurate data basis is provided for the evaluation of the turbulence intensity and the generating capacity of the wind power plant and the early-stage site selection or the later evaluation of the wind power plant.
Drawings
The above and other objects and features of the present invention will become more apparent from the following description taken in conjunction with the accompanying drawings, in which:
FIG. 1 is a flow chart illustrating a method of determining wind speed according to an exemplary embodiment of the present invention;
fig. 2 is a block diagram illustrating a structure of an apparatus for determining a wind speed according to an exemplary embodiment of the present invention;
FIG. 3 is a schematic view illustrating a wake formed by an incoming flow behind a rotor of a wind turbine generator set according to an exemplary embodiment of the present invention;
fig. 4 is a schematic view showing a projection of a wake formed by an incoming flow behind a wind rotor of a wind park intersecting a swept plane of a wind rotor of a downstream wind park according to an exemplary embodiment of the invention.
Detailed Description
Hereinafter, embodiments of the present invention will be described in detail with reference to the accompanying drawings.
Fig. 1 is a flowchart illustrating a method of determining a wind speed according to an exemplary embodiment of the present invention. Fig. 2 is a block diagram illustrating a structure of an apparatus for determining a wind speed according to an exemplary embodiment of the present invention. An implementation of determining wind speed will be described in detail below with reference to fig. 1 and 2.
Referring to fig. 1, the method of determining wind speed includes the steps of:
in step 110, the incoming wind speed at any wind turbine generator set in the wind farm may be obtained.
In step 120, a projected area formed by the intersection of the wake formed by the incoming flow behind the rotor of any wind park with the swept plane of the rotor of the downstream wind park may be determined.
In step 130, a swept area formed by the rotor of the downstream wind park on the sweep plane of the rotor of the downstream wind park may be determined.
In step 140, a wind speed in an overlap region between a projected area formed by the wake intersecting the swept plane of the wind rotor of the downstream wind park and the swept area of the wind rotor of the downstream wind park may be determined and the wind speed in the overlap region is determined as the wind speed at the downstream wind park.
In the embodiment of the invention, the wake flow is divided into a plurality of wake flow areas such as a near field area, a far field area and a mixing area according to the distance from the downstream wind generating set. In an example, the wake may be partitioned according to a velocity deficit rate of the wake. In another example, the wake may be divided according to whether the energy transfer of the wake is energy transfer with the external environment.
It will be appreciated that the wake of each wake zone of the division has a different effect on the downstream wind park. For example, the near field region is generally a wake region directly affected by blade disturbance after a blade wheel of the wind generating set sweeps a plane, the far field region is generally a wake region less affected by the outside after the near field region of the wind generating set, and the mixing region is generally a wake region which has a stronger mixing effect with the outside environment and is outside the far field region. Therefore, in specific implementation, the influence of wake regions with different expression characteristics on wind speed calculation can be considered to model different wake regions, then wind speeds corresponding to different wake regions are calculated respectively based on different wake models, and further wind speed calculation results of different wake models are integrated to obtain a final effective wind speed (namely, an effective wind speed of a downstream wind generating set under the influence of wake).
In a preferred embodiment, the wake formed by the incoming flow behind the rotor of any wind turbine generator set may be divided into wake zones in step 120, and each projected zone formed by the intersection of each divided wake zone with the swept plane of the rotor of the downstream wind turbine generator set is determined, as shown in fig. 4 below, and the projected zone a formed by the intersection of the near field zone with the swept plane of the rotor of the downstream wind turbine generator set is determinedk，1A projection area A formed by intersecting the far field area and the swept plane of the wind wheel of the downstream wind generating setk，2And a projection area A formed by the intersection of the mixed area and the sweep plane of the wind wheel of the downstream wind generating setk，3。
Further, in this embodiment, the wind speed in each overlap region between each projected region and the swept region of the rotor of the downstream wind park may be determined at step 140; and comprehensively determining the wind speed in the overlap area between the projected area and the swept area formed by the intersection of the wake and the swept plane of the wind rotor of the downstream wind park based on the weight that each overlap area between each projected area and the swept area has respectively with respect to the swept area (for example, including but not limited to taking the area ratio between the overlap area and the swept area as the weight that the overlap area has with respect to the swept area) and the wind speed in each overlap area between each projected area and the swept area.
In addition, the wind speed at the downstream wind generating set can be corrected by further calculating the turbulence intensity at the downstream wind generating set, so that the calculation result of the wind speed at the downstream wind generating set is converged, and the accuracy of wind speed estimation is further improved.
In another preferred embodiment, the turbulence intensity at the downstream wind park may be further determined from the wind speed at the downstream wind park determined in step 140; then, correcting the wind speed at the downstream wind generating set based on the turbulence intensity at the downstream wind generating set until a difference between the wind speed at the downstream wind generating set and the corrected wind speed at the downstream wind generating set is less than a predetermined threshold; finally, the corrected wind speed at the downstream wind turbine generator set is determined as the wind speed at the downstream wind turbine generator set.
It should be understood that, when implemented specifically, any of the above embodiments for determining wind speed may be implemented separately in the method, or the above embodiments for determining wind speed may be combined together to achieve the determination of wind speed.
Referring to fig. 2, the apparatus for determining a wind speed according to the present invention may include a wind speed acquisition unit 210, a projection area determination unit 220, a sweep area determination unit 230, and a first wind speed determination unit 240.
Specifically, the wind speed obtaining unit 210 may be used to obtain the wind speed at any wind generating set in the wind farm; the projection area determination unit 220 may be configured to determine a projection area formed by intersection of a wake formed by an incoming flow behind a wind rotor of any wind park with a swept plane of a wind rotor of a downstream wind park; the swept area determination unit 230 may be configured to determine a swept area formed by the rotor of the downstream wind park on a swept plane of the rotor of the downstream wind park; the first wind speed determination unit 240 may be configured to determine a wind speed in an overlap region between a projected area and a swept area formed by the wake intersecting the swept plane of the wind rotor of the downstream wind park and determine the wind speed in the overlap region as the wind speed at the downstream wind park.
As previously mentioned, the wake may comprise a plurality of wake regions, and the wake of each wake region has a different effect on the downstream wind park.
Therefore, in order to further improve the accuracy of the wind speed estimation, in a preferred embodiment, the projection region determining unit 220 may further include a wake region dividing unit (not shown) and a projection region determining subunit (not shown). Specifically, the wake region dividing molecular unit may be configured to divide the wake into a plurality of wake regions; the projection area determination subunit may be configured to determine each projection area formed by intersection of each divided wake area with a swept plane of a wind rotor of a downstream wind park, as shown later in fig. 4, of a projection area a formed by intersection of a near field area with a swept plane of a wind rotor of a downstream wind parkk，1A projection area A formed by intersecting the far field area and the swept plane of the wind wheel of the downstream wind generating setk，2And a projection area A formed by the intersection of the mixed area and the sweep plane of the wind wheel of the downstream wind generating setk，3。
Further, in this embodiment, the first wind speed determination unit 240 may further include a regional wind speed determination subunit (not shown) and an equivalent wind speed determination subunit (not shown). In particular, the regional wind speed determination subunit may be operable to determine wind speeds in each overlap region between each projected region and the swept region; the equivalent wind speed determination subunit may be configured to synthetically determine the wind speed in the overlap region between the projected area and the swept area formed by the intersection of the wake with the swept plane of the wind rotor of the downstream wind park based on a weight that each overlap region between each projected area and the swept area has respectively with respect to the swept area (e.g. including but not limited to taking the area ratio between the overlap region and the swept area as the weight that the overlap region has with respect to the swept area) and the wind speed in each overlap region between each projected area and the swept area.
In addition, as described above, the wind speed at the downstream wind turbine generator set can be further corrected by calculating the turbulence intensity at the downstream wind turbine generator set, so that the calculation result of the wind speed at the downstream wind turbine generator set is converged, and the accuracy of wind speed estimation is further improved.
In another preferred embodiment, the apparatus may further include: a turbulence intensity determining unit (not shown), a wind speed correcting unit (not shown), and a second wind speed determining unit (not shown). Specifically, the turbulence intensity determination unit is used for determining the turbulence intensity at the downstream wind generating set according to the wind speed at the downstream wind generating set; the wind speed correction unit is used for correcting the wind speed at the downstream wind generating set based on the turbulence intensity at the downstream wind generating set until the difference between the wind speed at the downstream wind generating set and the corrected wind speed of the downstream wind generating set is smaller than a preset threshold value; the second wind speed determination unit is used for determining the corrected wind speed at the downstream wind generating set as the wind speed at the downstream wind generating set.
It should be understood that, when implemented specifically, any one of the above embodiments for determining wind speed may be implemented in the apparatus, and the above embodiments for determining wind speed may also be combined together to determine wind speed.
Fig. 3 is a schematic view illustrating a wake formed by an incoming flow behind a rotor of a wind turbine generator set according to an exemplary embodiment of the present invention. Fig. 4 is a schematic view showing a projection of a wake formed by an incoming flow behind a wind rotor of a wind park intersecting a swept plane of a wind rotor of a downstream wind park according to an exemplary embodiment of the invention. One specific implementation of determining wind speed is described in further detail below with reference to fig. 3 and 4.
As shown in FIG. 3, when the incoming flow (the wind speed is U)i) Wind turbine generator turbineiThe incoming wind flows through the turbine of the wind generating setiThe wake, which is formed later and is elongated as shown in the figure, can be divided into three wake regions, a near-field region (the darkest part of the color as shown in fig. 3), a far-field region (the lighter part of the color as shown in fig. 3) and a mixed region (the part of the color near white as shown in fig. 3).
As shown in FIG. 4, each wake zone (i.e., the near-field zone, the far-field zone, and the mixing zone shown in FIG. 3) is divided with a downstream wind turbine generator set turbinekOf the wind wheel intersect to form a projection area Ak，1、Ak，2And Ak，3Are all connected with the downstream wind generating set turbinekSwept area a of the wind wheelkWith partial overlap (i.e., overlap region a shown in fig. 4)overlap，k，1、Aoverlap，k，2And Aoverlap，k，3)。
In particular, the method and apparatus for determining wind speed may be implemented using the following formulas involved in the particular implementation:
first, the wind turbine generator set turbo may be determined using the following equation (1)iCorresponding to different wake regions j (i.e., corresponding to the near-field region, the far-field region, and the blend region, respectively):
wherein, cw，i，jFor wind generating sets turbineiDifferent wake region j of the same wake pattern, DiFor wind generating sets turbineiDiameter of the rotor, ke，iFor wind generating sets turbineiInitial wake expansion coefficient of (2), XiFor wind generating sets turbineiX is the abscissa of any point in the wake region, X-XiTo any point to wind generating set turboiDistance of the machine-site, mu，j(γi) For being turned into turbine with wind generating setiOf the different wake sectors j (which is related to the yaw angle γ)iLinear correlation).
Then, the wake deficit coefficient c obtained from the formula (1) can be used as the basisw，i，jWind turbine generator set turbo is determined using the following equations (2) and (3), respectivelyiThe wind speed corresponding to different wake areas j and the width of different wake areas j of the wind generating set turbinei:
Uw，i，j＝Ui(1-2aicw，i，j)(2)
Dw，i，j＝max(Di+2ke，ime，j(x-Xi)，0) (3)
wherein, Uw，i，jFor wind generating sets turbineiCorresponding to different wake areas j, aiIs an axial induction factor (which can be obtained from a wind speed lookup table), UiFor wind generating sets turbineiWind speed of (c)w，i，jAnd the wake loss coefficients corresponding to different wake regions j.
Wherein D isw，i，jFor wind generating sets turbineiOf the near field region (shown in fig. 3 as wake width D of the near field region)w，i，1Wake width D of far field regionw，i，2And wake width D of the mixing zonew，i，3)，DiFor wind generating sets turbineiDiameter of the wind wheel of (1), me，jFor wind generating sets turbineiOf different wake regions j, ke，iFor wind generating sets turbineiWake expansion coefficient of (X)iFor wind generating sets turbineiX is the abscissa of any point in the wake region, X-XiTo any point to wind generating set turboiThe machine location point of (a).
Further, the wind turbine generator set turbo may be determined using the following equations (4), (5) and (6)iWake offset (which is mainly defined by yaw angle ξ)iAnd coriolis force (i.e., earth rotation):
Δrotate，i＝ad+bd(x-Xi) (5)
Yw，i＝Yi+Δyaw，i+Δrotate，i(6)
wherein, Deltayaw，iTo be controlled by a yaw angle ξi(x) Caused byOffset, ξi(x) Included angle of central line of wake, XiFor wind generating sets turbineiX is the abscissa of any point in the wake region, X-XiTo any point to wind generating set turboiThe machine location point of (a).
Wherein, Deltarotate，iIs the amount of deflection caused by the Coriolis force, ad、bdFor rotationally offsetting linear equation coefficients, XiFor wind generating sets turbineiX is the abscissa of any point in the wake region, X-XiTo any point to wind generating set turboiThe machine location point of (a).
Wherein, Yw，iFor wind generating sets turbineiWake offset of, YiiFor wind generating sets turbineiOrdinate of the machine position, Δyaw，iFor the offset caused by yaw angle, Δrotate，iIs the amount of deflection caused by coriolis forces.
Further, the wind generating set turbo can be based oniWake flow deviation and turbine of wind generating setiOf different wake regions jw，i，jAnd a downstream wind turbine generator set turbinekSwept area a of the wind turbinekTo determine the turbine of the wind turbineiDifferent wake areas j and downstream wind turbine generator systems turboiThe swept areas of the wind wheels intersect to form a projection area Ak，1、Ak，2And Ak，3Turbine connected with downstream wind generating setkSwept area a of the wind wheelkOverlap region A therebetweenoverlap，k，jThen, the wind generating set is turboiOf different wake regions jk，1、Ak，2And Ak，3Turbine connected with downstream wind generating setkSwept area a of the wind wheelkOverlap region A therebetweenoverlap，k，jTurbine connected with downstream wind generating setiSwept area a of the wind wheelkThe area ratio between the two is used as turbine of the wind generating setiDifferent wake areas j of the wind speed Uw，i，jThe weights of the wind turbine generators are comprehensively determined to obtain the turbo of the downstream wind turbine generator systemkThe wind speed of (c).
Specifically, the following equation (7) may be used to determine the downstream wind turbine generator set turbokThe wind speed:
wherein, Ueff，kFor downstream wind generating set turbokWind speed of (A)kFor downstream wind generating set turbokOf the wind wheel, Aover1ap，k，jAnd AkThe ratio of (A) represents the wind turbine generator system turboiOf different wake regions jk，1、Ak，2And Ak，3Turbine connected with downstream wind generating setkSwept area a of the wind wheelkOverlap region A therebetweenoverlap，k，jTurbine connected with downstream wind generating setiSwept area a of the wind wheelkThe area ratio therebetween. a iskFor downstream wind generating set turbokAxial induction factor (which may be dependent on the wind speed U)iObtained by looking up a table). c. Cw，i，jFor wind generating sets turbineiDifferent wake areas j in the wake of the downstream wind power plant turbokWake deficit coefficient ofiAnd XkAre wind generating sets turbine respectivelyiAnd a downstream wind turbine generator set turbinekAbscissa, X, of the machine pointi＜XkRepresentation of downstream wind turbine generator systems turbokMachine site relative to wind generating set turbineiIn the downstream direction of the machine site.
Further, in order to determine a more accurate wind speed value, the determined downstream wind turbine generator system turbo may be further based onkWind speed U ofeff，kDetermining downstream wind turbine generator system turbokTo correct the wind turbine using the determined additional turbulence intensityGroup turbineiInitial wake expansion coefficient of (a):
wherein k ise，iFor wind generating sets turbineiCoefficient of wake expansion, Tadd，kFor downstream wind generating set turbokAdditional turbulence intensity of (U)eff，kFor downstream wind generating set turbokReference turbulence intensity of (A), TambientAnd TrefRespectively ambient turbulence intensity and reference turbulence intensity, a and b are constants, CT，iFor wind generating sets turbinekThe thrust coefficient (which may be obtained from a wind speed lookup table).
Wind generating set turbo obtainable based on the above formula (10)iCoefficient of wake expansion ke，iRecalculating the downstream wind turbine generator sets turbo using the above equation (7)kWind speed U ofeff，kAnd calculating the downstream wind generating set turbo againkWind speed U ofedd，kWith the previously calculated downstream wind turbine turbokWind speed U ofeff，kComparing, and when the difference value between the two meets the preset threshold value, recalculating the downstream wind generating set turbokWind speed U ofeff，kDetermined as a downstream wind turbine generator set turbokWind speed U ofeff，k(ii) a Otherwise, the calculation process of the wake expansion coefficient described above is repeatedly executed to continue iterative convergence. This is further based on the effective turbulence intensity to the wind speed Ueff，kThe process of performing iterative calculations may further improve the accuracy of the wind speed estimation.
Therefore, the implementation divides the wake flow of the wind generating set into three different wake flow areas, respectively considers the influence of the wake flow on the downstream wind generating set, and obtains the wind speed of the downstream wind generating set based on calculation. The method is more accurate in calculation of the wind speed of each wind generating set in the wind power plant, and therefore more reliable and accurate data basis is provided for evaluation of the turbulence intensity and the generating capacity of the wind power plant and early-stage site selection or later evaluation of the wind power plant.
The above-described method according to the present invention can be implemented in hardware, firmware, or as software or computer code storable in a recording medium such as a CD ROM, a RAM, a floppy disk, a hard disk, or a magneto-optical disk, or as computer code originally stored in a remote recording medium or a non-transitory machine-readable medium and to be stored in a local recording medium downloaded through a network, so that the method described herein can be stored in such software processing on a recording medium using a general-purpose computer, a dedicated processor, or programmable or dedicated hardware such as an ASIC or FPGA. It will be appreciated that the computer, processor, microprocessor controller or programmable hardware includes memory components (e.g., RAM, ROM, flash memory, etc.) that can store or receive software or computer code that, when accessed and executed by the computer, processor or hardware, implements the processing methods described herein. Further, when a general-purpose computer accesses code for implementing the processes shown herein, execution of the code transforms the general-purpose computer into a special-purpose computer for performing the processes shown herein.
While the invention has been shown and described with reference to the preferred embodiments, it will be understood by those skilled in the art that various changes and modifications may be made therein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (6)
1. A method of determining wind speed, the method comprising:
acquiring an incoming flow wind speed of any wind generating set in a wind power plant;
determining a projection area formed by intersecting a wake flow formed by the incoming flow behind a wind wheel of any one of the wind generating sets and a swept plane of a wind wheel of a downstream wind generating set;
determining a sweep area formed by a wind rotor of the downstream wind turbine generator set on the sweep plane;
determining a wind speed in an overlap region between a projected area formed by the wake intersecting the swept plane and the swept area, and determining the wind speed in the overlap region as a wind speed at the downstream wind turbine generator set,
wherein the step of determining a projection area formed by the wake intersecting the sweep plane comprises:
dividing the wake into a plurality of wake regions;
determining each projected area formed by each divided wake area intersecting the sweep plane,
wherein the step of determining the wind speed in an overlap region between a projected area formed by the wake intersecting the sweep plane and the sweep area comprises:
determining a wake deficit coefficient of each divided wake region;
determining a wind speed in each divided wake region based on the wake deficit coefficient of each divided wake region;
determining each overlap area between each projected area and a swept area formed by intersection of each divided wake area and the swept plane based on a wake offset of the any wind turbine generator set, a wake width of each divided wake area, and a swept area formed by a wind rotor of a downstream wind turbine generator set on the swept plane;
determining a wind speed in each overlap region between each projected region and the swept region using the wind speed in each wake region divided.
2. The method of claim 1, wherein the step of determining the wind speed in an overlap region between a projected area formed by the wake intersecting the sweep plane and the sweep area further comprises:
determining a wind speed in an overlap region between a projection region formed by the wake intersecting the sweep plane and the sweep region based on a weight that each overlap region between the each projection region and the sweep region has, respectively, with respect to the sweep region and the wind speed in each overlap region between the each projection region and the sweep region.
3. The method of claim 1, wherein the method further comprises:
determining turbulence intensity at the downstream wind generating set according to the wind speed at the downstream wind generating set;
correcting the wind speed at the downstream wind power generation unit based on the turbulence intensity at the downstream wind power generation unit until a difference between the wind speed at the downstream wind power generation unit and the corrected wind speed at the downstream wind power generation unit is less than a predetermined threshold;
determining the corrected wind speed at the downstream wind turbine generator set as the wind speed at the downstream wind turbine generator set.
4. The method of any one of claims 1-3, wherein the wake comprises at least one of a near-field region, a far-field region, and a mixed region.
5. A computer-readable storage medium, in which a computer program is stored which, when being executed by a processor, carries out the method of determining a wind speed according to any one of claims 1-4.
6. A computer device, characterized in that the computer device comprises:
a processor;
memory storing a computer program which, when executed by a processor, carries out the method of determining a wind speed according to any one of claims 1-4.
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| CN101852172A (en) * | 2010-03-09 | 2010-10-06 | 山东科技大学 | Method for calculating input wind speed of wind generating sets according to wake effect in wind power station |
| CN101949363A (en) * | 2010-09-21 | 2011-01-19 | 山东科技大学 | Method for grouping wind generating sets by taking input wind speed and random fluctuation of wind direction of wind farm into consideration |
| CN102142103A (en) * | 2011-04-15 | 2011-08-03 | 河海大学 | Real-coded genetic algorithm-based optimizing method for micrositing of wind power station |
| CN103389388B (en) * | 2012-05-08 | 2015-08-19 | 华锐风电科技(集团)股份有限公司 | Method for forecasting and device thereof and power forecasting method and system thereof |
| US9617975B2 (en) * | 2012-08-06 | 2017-04-11 | General Electric Company | Wind turbine yaw control |
| US9188677B2 (en) * | 2013-05-01 | 2015-11-17 | Sandia Corporation | Imaging doppler lidar for wind turbine wake profiling |
| CN103324863B (en) * | 2013-07-11 | 2016-06-15 | 北京金风科创风电设备有限公司 | Method for correcting measured power curve of wind driven generator by using actually measured turbulence intensity |
| CN103605912B (en) * | 2013-12-10 | 2016-06-08 | 武汉大学 | A kind of wind power plant power external characteristic modeling method |
| CN103886179B (en) * | 2014-02-25 | 2017-05-31 | 国家电网公司 | A kind of wind electric field blower polymerization based on wake effect point group |
| CN105068148B (en) * | 2015-07-14 | 2017-06-27 | 北京金风科创风电设备有限公司 | Wind power plant gust prediction method and system |
| CN105354632B (en) * | 2015-10-26 | 2019-03-19 | 江苏省电力公司电力经济技术研究院 | A kind of wind power optimization allocation strategy considering wake effect |
| CN105335617B (en) * | 2015-11-05 | 2017-12-15 | 北京金风科创风电设备有限公司 | Method and device for evaluating wake effect of wind power plant |
| CN105649878B (en) * | 2015-12-31 | 2018-11-13 | 北京金风科创风电设备有限公司 | Wind energy capturing method and device of wind generating set and wind generating set |
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2017
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| WO2019119722A1 (en) | 2019-06-27 |
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