Offshore wind farm arrangement optimization method, device, equipment and medium

Abstract

The application relates to the technical field of wind farm layout, and particularly provides a near-shore region wind farm arrangement optimization method, device, equipment and medium, aiming to solve the technical problem of unreasonable near-shore region wind farm layout, and thus low power generation efficiency of wind turbine generators. For the purpose, the application comprises the following steps: acquiring a wind farm construction region, a wind turbine generator quantity and wind resource data; obtaining background flow field wind speed and background flow field turbulence intensity according to the wind resource data; obtaining a wind farm generator initial population according to the wind farm construction region and the wind turbine generator quantity; wherein the wind farm generator initial population comprises position coordinates of multiple wind turbine generators; obtaining total power generation according to the background flow field wind speed and the background flow field turbulence intensity; and performing optimization processing on the wind farm generator initial population according to the total power generation, so as to obtain wind farm generator arrangement.

Description

Technical Field

[0001] This application relates to the field of wind farm layout technology, specifically providing a method, apparatus, equipment, and medium for optimizing the layout of wind farms in nearshore areas. Background Technology

[0002] Wind energy is an important component of clean energy development. As wind farms become larger and their operating environments become more diverse, the importance of wind farm layout optimization research is becoming increasingly prominent.

[0003] In existing technologies, wind farms are typically arranged along coastlines in straight lines, fan shapes, or ring shapes. During wind turbine operation, the surface roughness changes from the coastline to the turbine's installation location, causing a transition phase in the regional flow field. Furthermore, wind speed and turbulence characteristics vary spatially, leading to inaccurate flow monitoring by the anemometer tower. Additionally, the turbine's wake is affected during this transition phase. Therefore, current wind farm layouts contribute to the technical problem of low power generation efficiency for wind turbines.

[0004] Accordingly, there is a need in this field for a new method for optimizing the layout of wind farms in nearshore areas to address the above-mentioned problems. Summary of the Invention

[0005] In order to overcome the above-mentioned defects, this application is made to provide a solution or at least a partial solution to the technical problem in the prior art that the unreasonable layout of wind farms in near-shore areas leads to low power generation efficiency of wind turbine generators.

[0006] In a first aspect, this application provides a method for optimizing the layout of wind farms in nearshore areas, comprising:

[0007] Obtain data on wind farm construction areas, number of wind turbine units, and wind resources;

[0008] Based on the wind resource data, the background wind speed and background turbulence intensity are obtained.

[0009] Based on the wind farm construction area and the number of wind turbine units, an initial population of wind farm units is obtained; wherein, the initial population of wind farm units includes the location coordinates of multiple wind turbine units;

[0010] The total power generation is obtained based on the background wind speed and the background turbulence intensity.

[0011] Based on the total power generation, the initial population of the wind farm units is optimized to obtain the wind farm unit layout.

[0012] In one technical solution of the aforementioned method for optimizing the layout of wind farms in nearshore areas, obtaining the total power generation based on the background wind speed and the background turbulence intensity includes:

[0013] Based on the flow direction behind the wind turbine, the rotor diameter, and the turbulence intensity of the background flow field, the wake velocity deficit half-width and the standard deviation of the Gaussian distribution in the wake edge region of the wind turbine are obtained.

[0014] The additional turbulence intensity distribution is obtained based on the wake velocity deficit half-width of the wind turbine, the standard deviation of the Gaussian distribution in the wake edge region, and the ground correction.

[0015] The distribution of turbulence intensity is obtained based on the additional turbulence intensity distribution and the background flow field turbulence intensity;

[0016] Based on the distribution of turbulence intensity, the corrected thrust coefficient is obtained;

[0017] The wake velocity deficit is obtained based on the background flow field wind speed, air field wind speed, thrust coefficient, and the corrected thrust coefficient.

[0018] Based on the aforementioned additional turbulence intensity distribution, the inflow additional flow-direction turbulence intensity is obtained;

[0019] The inflow velocity loss is obtained based on the average velocity loss.

[0020] The wind speed in front of the wheel hub is obtained based on the ambient incoming wind speed and the inflow velocity deficit.

[0021] The current output power of the wind turbine is obtained based on the wind speed in front of the hub.

[0022] The total output power is obtained based on the wind speed, the current output power of the wind turbine, the number of wind turbines, and wind resource data.

[0023] In one technical solution of the aforementioned method for optimizing the layout of wind farms in nearshore areas, obtaining the ground correction includes:

[0024] The correction factor is obtained based on the wake radius and wake half-width;

[0025] The ground correction is obtained based on the correction coefficient and the correction amount.

[0026] In one technical solution of the aforementioned method for optimizing the layout of wind farms in nearshore areas, the step of obtaining the wake velocity deficit based on the background flow field wind speed, air field wind speed, thrust coefficient, and corrected thrust coefficient includes:

[0027] In any iteration, obtain the ratio of the i-th background convection velocity to the reference wind speed;

[0028] The i-th wake velocity deficit is obtained based on the background flow field wind speed, thrust coefficient, corrected thrust coefficient, and the ratio of the i-th background convection velocity to the reference wind speed.

[0029] Based on the air field wind speed and the background flow field wind speed, the ratio of the (i+1)th background convection velocity to the reference wind speed is obtained;

[0030] The ratio change rate is obtained based on the ratio of the i-th background convection velocity to the reference wind speed and the ratio of the (i+1)-th background convection velocity to the reference wind speed.

[0031] Once the rate of change of the ratio is determined to be less than a preset threshold, the ratio of the I-th background convection velocity to the reference wind speed is obtained; where I is the iteration number.

[0032] The wake velocity deficit is obtained based on the background flow field wind speed, air field wind speed, thrust coefficient, the distribution of turbulence intensity, and the ratio of the first background convection velocity to the reference wind speed.

[0033] In one technical solution of the above-mentioned method for optimizing the layout of wind farms in nearshore areas, obtaining the corrected thrust coefficient based on the distribution of turbulence intensity includes:

[0034] The adjustment coefficient is obtained based on the distribution of turbulence intensity and the background wind speed.

[0035] The corrected thrust coefficient is obtained based on the adjustment coefficient, the background flow field wind speed, and the rotor diameter.

[0036] In one technical solution of the above-mentioned method for optimizing the layout of wind farms in nearshore areas, obtaining the turbulence intensity distribution based on the additional turbulence intensity distribution and the background flow field turbulence intensity includes:

[0037] Based on the additional turbulence intensity distribution and the background flow field turbulence intensity, the sum of squares of turbulence is obtained;

[0038] The distribution of turbulence intensity is obtained based on the sum of squares of the turbulence.

[0039] In one technical solution of the above-mentioned method for optimizing the layout of wind farms in nearshore areas, the step of optimizing the initial population of wind farm units based on the total power generation to obtain the wind farm layout includes:

[0040] In each round, obtain the population of wind farm units for the i-th wind farm;

[0041] Based on the i-th wind farm unit population, the i-th variant wind farm unit population is obtained;

[0042] Based on the i-th variant wind farm unit population, the (i+1)-th wind farm unit population is obtained;

[0043] When the total power generation is determined to be the maximum value, the layout of the Nth wind farm unit is obtained, and the optimization process is stopped; where N is the total number of cycles, and the layout of the Nth wind farm unit is the wind farm arrangement.

[0044] Secondly, this application provides a device for optimizing the layout of wind farms in nearshore areas, comprising:

[0045] The acquisition module is used to acquire data on wind farm construction areas, the number of wind turbine units, and wind resources.

[0046] The analysis module is used to obtain the background wind speed and background turbulence intensity based on the wind resource data.

[0047] The processing module is used to obtain an initial population of wind farm units based on the wind farm construction area and the number of wind turbine units; wherein, the initial population of wind farm units includes the location coordinates of multiple wind turbine units;

[0048] The processing module is also used to obtain the total power generation based on the background wind speed and the background turbulence intensity.

[0049] The optimization module is used to optimize the initial population of wind farm units based on the total power generation to obtain the wind farm unit layout.

[0050] Thirdly, this application provides a device for optimizing the layout of offshore wind farms, including a processor and a storage device, wherein the storage device is adapted to store multiple program codes, and the program codes are adapted to be loaded and run by the processor to perform the method described in any one of the first aspects.

[0051] Fourthly, this application provides a computer-readable storage medium storing a plurality of program codes adapted to be loaded and run by a processor to perform the method described in any one of the first aspects.

[0052] This application provides a method, apparatus, equipment, and medium for optimizing the layout of wind farms in nearshore areas. The method specifically includes: acquiring data on the wind farm construction area, the number of wind turbines, and wind resources; obtaining the background wind speed and turbulence intensity based on the wind resource data; obtaining an initial population of wind farm turbines based on the wind farm construction area and the number of wind turbines; wherein the initial population of wind farm turbines includes the location coordinates of multiple wind turbines; obtaining the total power generation based on the background wind speed and turbulence intensity; and optimizing the initial population of wind farm turbines based on the total power generation to obtain the wind farm turbine layout, thereby improving the power generation efficiency of wind turbines in nearshore areas. Attached Figure Description

[0053] The disclosure of this application will become more readily understood with reference to the accompanying drawings. It will be readily understood by those skilled in the art that these drawings are for illustrative purposes only and are not intended to limit the scope of protection of this application. Furthermore, similar numbers in the drawings are used to denote similar components, wherein:

[0054] Figure 1 A flowchart illustrating an embodiment of a method for optimizing the layout of wind farms in nearshore areas, provided in this application.

[0055] Figure 2 A flowchart illustrating a second embodiment of a method for optimizing the layout of wind farms in nearshore areas, provided in this application.

[0056] Figure 3 A flowchart illustrating a third embodiment of a method for optimizing the layout of wind farms in nearshore areas, as provided in this application.

[0057] Figure 4 A flowchart illustrating a fourth embodiment of a method for optimizing the layout of wind farms in nearshore areas, as provided in this application.

[0058] Figure 5 A flowchart illustrating a fifth embodiment of a method for optimizing the layout of wind farms in nearshore areas, provided as an example of this application.

[0059] Figure 6 A flowchart illustrating a sixth embodiment of a method for optimizing the layout of wind farms in nearshore areas, as provided in this application.

[0060] Figure 7 A flowchart illustrating Embodiment 7 of a method for optimizing the layout of wind farms in nearshore areas, provided as an embodiment of this application;

[0061] Figure 8 A schematic diagram of an embodiment of a wind farm layout optimization device in an offshore area provided in this application;

[0062] Figure 9 This is a schematic diagram of a first embodiment of a wind farm layout optimization device in an offshore area, provided as an example of this application.

[0063] List of reference numerals :

[0064] 11: Acquisition module; 12: Analysis module; 13: Processing module; 14: Optimization module; 21: Processor; 22: Memory. Detailed Implementation

[0065] Some embodiments of this application are described below with reference to the accompanying drawings. Those skilled in the art should understand that these embodiments are merely illustrative of the technical principles of this application and are not intended to limit the scope of protection of this application.

[0066] In the description of this application, "module" and "processor" can include hardware, software, or a combination of both. A module can include hardware circuitry, various suitable sensors, communication ports, memory, and may also include software components, such as program code, or a combination of software and hardware. A processor can be a central processing unit, microprocessor, image processor, digital signal processor, or any other suitable processor. The processor has data and / or signal processing capabilities. The processor can be implemented in software, in hardware, or a combination of both. Non-transitory computer-readable storage media includes any suitable medium capable of storing program code, such as magnetic disks, hard disks, optical disks, flash memory, read-only memory, random access memory, etc. The term "A and / or B" means all possible combinations of A and B, such as only A, only B, or A and B. The terms "at least one A or B" or "at least one of A and B" have a similar meaning to "A and / or B" and can include only A, only B, or A and B. The singular terms "a" or "this" can also include plural forms.

[0067] In the existing technology, when installing wind power generation equipment in nearshore areas, straight, fan-shaped or ring-shaped arrangements are often used to arrange the wind power generation equipment. However, this arrangement does not take into account the changes in the flow field in the nearshore area, which causes changes in the wake of the wind turbine, resulting in the technical problem of low power generation efficiency of wind turbines in wind farms with this arrangement.

[0068] Based on this, in order to solve the above-mentioned technical problems, this application provides a method for optimizing the layout of wind farms in nearshore areas, so as to optimize the layout of wind turbine units and thereby improve the power generation efficiency of wind turbine units.

[0069] The technical solution of this application and how the technical solution of this application solves the above-mentioned technical problems are described in detail below with specific embodiments. These specific embodiments can be combined with each other, and the same or similar concepts or processes may not be described again in some embodiments. The embodiments of this application will now be described with reference to the accompanying drawings.

[0070] Figure 1 This is a flowchart illustrating an embodiment of a method for optimizing the layout of wind farms in nearshore areas, provided in this application. Figure 1 As shown, specifically, the method includes:

[0071] Step S101: Obtain data on the wind farm construction area, the number of wind turbines, and wind resources.

[0072] In this embodiment, the wind farm construction area includes a macroscopic topographic map of the wind farm area and the planned construction scope of the wind farm. Wind resource data includes wind speed and turbulence intensity for each wind direction obtained from the meteorological tower.

[0073] In this embodiment, for example, the wind farm construction area is 2400 meters wide and 1800 meters long, located 8 kilometers from the coastline. There are 25 wind turbine units.

[0074] Step S102: Based on the wind resource data, obtain the background flow field wind speed and background flow field turbulence intensity.

[0075] In this embodiment, computational fluid dynamics (CFD) simulation software was used to obtain the distribution of background wind speed and turbulence intensity in the wind farm construction area under sixteen wind directions. Furthermore, based on wind resource data, the background turbulence intensity for each wind direction and corresponding wind speed range was determined within the CFD simulation software.

[0076] Step S103: Obtain the initial population of wind farm units based on the wind farm construction area and the number of wind turbine units.

[0077] In this embodiment, the initial population of wind farm units includes the location coordinates of multiple wind turbine units.

[0078] In this embodiment, within the wind farm construction area, multiple wind turbine coordinates are randomly generated based on the number of wind turbines, and each wind turbine coordinate is an individual.

[0079] Step S104: Obtain the total power generation based on the background wind speed and the background turbulence intensity.

[0080] In this embodiment, based on the background wind speed and background turbulence intensity, the total power generation of individuals in the initial population is obtained by coupling the single-machine wake velocity model under roughness abrupt change, the turbulence intensity model, the wake velocity linear superposition method, and the turbulence intensity superposition method.

[0081] Step S105: Optimize the initial population of wind farm units based on the total power generation to obtain the wind farm unit layout.

[0082] In this embodiment, the initial population of wind turbine units is optimized multiple times based on the total power generation to obtain the wind farm unit layout, so that the wind turbine units in the wind farm can obtain the maximum total power generation when arranged in this wind farm unit layout.

[0083] In this embodiment, data on the wind farm construction area, the number of wind turbines, and wind resources are acquired. Based on the wind resource data, the background wind speed and turbulence intensity are obtained. Based on the wind farm construction area and the number of wind turbines, an initial population of wind farm turbines is obtained, including the location coordinates of multiple wind turbines. Based on the background wind speed and turbulence intensity, the total power generation is obtained. Based on the total power generation, the initial population of wind farm turbines is optimized to obtain the wind farm turbine layout, which is different from existing methods. Regarding the issue of unreasonable layout of wind farms in nearshore areas, which leads to low power generation efficiency of offshore wind turbines, this application addresses this problem by obtaining background wind speed and turbulence intensity based on wind resource data, and then determining the initial wind farm turbine population based on the wind farm construction area and the number of wind turbines. The total power generation is then calculated based on the background wind speed and turbulence intensity. Based on the total power generation, the initial wind farm turbine population is optimized to obtain the wind farm turbine layout, thereby improving the power generation efficiency of wind turbines in nearshore areas.

[0084] Figure 2 This is a flowchart illustrating a second embodiment of a method for optimizing the layout of wind farms in nearshore areas, as provided in this application. Figure 2 As shown, the specific implementation of step S104 includes:

[0085] Step S201: Based on the flow direction behind the wind turbine, the rotor diameter, and the turbulence intensity of the background flow field, obtain the half-width of the wake velocity deficit and the standard deviation of the Gaussian distribution in the wake edge region of the wind turbine.

[0086] In this embodiment, according to formula 1:

[0087] r 1 / 2 =1.18*(k w *x+ε*D) (1)

[0088] Obtain the half-width r of the wake velocity deficit of the wind turbine. 1 / 2 Among them, k w =0.09*I b0 +0.024, I b0 denoted as the background turbulence intensity, x as the flow direction position behind the wind turbine, and D as the rotor diameter.

[0089] In this embodiment, according to formula 2:

[0090]

[0091] We obtain ε. Where C T This is the thrust coefficient.

[0092] In this embodiment, according to formula 3:

[0093]

[0094] The standard deviation σ of the Gaussian distribution in the wake edge region was obtained. T .

[0095] Step S202: Based on the wake velocity deficit half-width of the wind turbine, the standard deviation of the Gaussian distribution in the wake edge region, and the ground correction, the additional turbulence intensity distribution is obtained.

[0096] In this embodiment, according to formula 4:

[0097]

[0098] The additional turbulence intensity distribution ΔIu is obtained, where δ(r) is the ground correction.

[0099] Step S203: Obtain the distribution of turbulence intensity based on the additional turbulence intensity distribution and the background flow field turbulence intensity.

[0100] In this embodiment, the distribution of additional turbulence intensity and the background flow field turbulence intensity are summed to obtain the distribution of turbulence intensity.

[0101] Step S204: Obtain the corrected thrust coefficient based on the distribution of turbulence intensity.

[0102] Step S205: Obtain the wake velocity deficit based on the background flow field wind speed, air field wind speed, thrust coefficient, and corrected thrust coefficient.

[0103] In this embodiment, the difference between the air field wind speed and the wake velocity is obtained. The ratio of this difference to the background flow field wind speed is the iterative formula. Based on the thrust coefficient and the correction force coefficient, the obtained formula is equivalent to the iterative formula. The iterative formula is iterated through the iterative conditions to obtain the wake velocity deficit.

[0104] Step S206: Obtain the inflow additional turbulence intensity based on the additional turbulence intensity distribution.

[0105] In this embodiment, according to formula 5:

[0106]

[0107] The inflow additional flow-direction turbulence intensity ΔIu is obtained. i (x,y,z). Where ΔIu i (x,y,z) represents the additional turbulence intensity at point (x,y,z) on the rotor of the current i-th wind turbine; q is true if and only if the i-th wind turbine is downstream of the j-th wind turbine. ij =1, otherwise, q ij =0; N is the number of wind turbines in the wind farm.

[0108] Step S207: Obtain the inflow velocity loss based on the average velocity loss.

[0109] In this embodiment, according to formula 6:

[0110]

[0111] The inflow velocity loss ΔU is obtained. i (x,y,z). Where ΔU i (x,y,z) represents the inflow velocity deficit at point (x,y,z) on the rotor of the i-th wind turbine; ΔU ij (x,y,z) represents the average velocity deficit of the j-th wind turbine at point (x,y,z) on the rotor of the i-th wind turbine; q is true if and only if the i-th wind turbine is downstream of the j-th wind turbine. ij =1, otherwise, q ij =0; N is the number of wind turbines in the wind farm.

[0112] Step S208: Obtain the wind speed in front of the wheel hub based on the ambient incoming wind speed and inflow velocity loss.

[0113] In this embodiment, according to formula 7:

[0114]

[0115] Get the wind speed U in front of the wheel hub i Among them, U i U represents the wind speed in front of the hub of the i-th wind turbine; U0 represents the ambient incoming wind speed. To calculate the average inflow velocity deficit at multiple points on the i-th wind turbine.

[0116] Step S209: Obtain the current output power of the wind turbine based on the wind speed in front of the hub.

[0117] In this embodiment, the current output power of the wind turbine under the current wind conditions is obtained based on the wind speed in front of the wind turbine hub and the power curve of the wind turbine. The power curve of the wind turbine represents the correspondence between the wind speed in front of the wind turbine hub and the output power of the wind turbine.

[0118] Step S210: Calculate the total output power based on wind speed, current wind turbine output power, number of wind turbines, and wind resource data.

[0119] In this embodiment, according to formula 8:

[0120]

[0121] The total output power P is obtained.total Among them, W jk Let the wind speed be u j The wind direction is θ k Wind conditions; P i For wind turbine i in wind condition W jk Output power at f(W) jk (W) is the wind condition. jk The probability of occurrence; N θ For wind direction; N u N represents the number of wind speed ranges selected for a single wind direction; N represents the number of units.

[0122] In this embodiment, based on the wind turbine's rear flow direction position, rotor diameter, and background turbulence intensity, the wake velocity deficit half-width and wake edge Gaussian distribution standard deviation are obtained. Based on the wake velocity deficit half-width, wake edge Gaussian distribution standard deviation, and ground correction, the additional turbulence intensity distribution is obtained. Based on the additional turbulence intensity distribution and background turbulence intensity, the turbulence intensity distribution is obtained. Based on the turbulence intensity distribution, the corrected thrust coefficient is obtained. Based on the background wind speed, airflow wind speed, thrust coefficient, and corrected thrust coefficient, the wake velocity deficit is obtained. Based on the additional turbulence intensity distribution, the inflow additional flow direction turbulence intensity is obtained. Based on the average velocity deficit, the inflow velocity deficit is obtained. Based on the ambient incoming wind speed and inflow velocity deficit, the wind speed in front of the hub is obtained. Based on the wind speed in front of the hub, the current wind turbine's output power is obtained. Based on the wind speed, the current wind turbine's output power, the number of wind turbines, and wind resource data, the total output power is obtained.

[0123] Figure 3 This is a flowchart illustrating a third embodiment of a method for optimizing the layout of wind farms in nearshore areas, as provided in this application. Based on the above embodiments, as... Figure 3 As shown, specifically, obtaining the ground correction in step S202 includes:

[0124] Step S301: Obtain the correction coefficient based on the wake radius and wake half-width.

[0125] In this embodiment, according to formula 9:

[0126]

[0127] The correction factor k1 is obtained. Where r is the wake radius, r 1 / 2 This is the wake half-width.

[0128] Step S302: Obtain the ground correction based on the correction factor and correction amount.

[0129] In this embodiment, according to formula 10:

[0130]

[0131] The ground correction δ(r) is obtained. Where α is the correction amount.

[0132] In this embodiment, a correction factor is obtained based on the wake radius and wake half-width; and a ground correction is obtained based on the correction factor and the correction amount.

[0133] Figure 4 This is a flowchart illustrating a fourth embodiment of a method for optimizing the layout of wind farms in nearshore areas, as provided in this application. Figure 4 As shown, one specific implementation of step S205 is as follows:

[0134] Step S401: In any iteration, obtain the ratio of the i-th background convection velocity to the reference wind speed.

[0135] In this embodiment, in the first iteration, the ratio of the first background convection velocity to the reference wind speed is 1.

[0136] Step S402: Based on the background flow field wind speed, thrust coefficient, corrected thrust coefficient, and the ratio of the i-th background convection velocity to the reference wind speed, obtain the i-th wake velocity deficit.

[0137] In this embodiment, according to formula 11:

[0138]

[0139] The i-th wake velocity deficit ΔU is obtained. Where U b0 H represents the background flow field wind speed. i (x) represents the ratio of the i-th background convective velocity to the reference wind speed, σ represents the standard deviation of the Gaussian distribution in the wake edge region, D represents the rotor diameter, and C represents the reference wind speed. T For thrust coefficient, To correct the thrust coefficient, r is the wake radius.

[0140] Step S403: Based on the air field wind speed and the background flow field wind speed, obtain the ratio of the (i+1)th background convection velocity to the reference wind speed.

[0141] In this embodiment, according to formula 12:

[0142]

[0143] The ratio H of the (i+1)th background convection velocity to the reference wind speed is obtained. i+1 (x). Wherein, U b For open field wind speed; U b0 The background flow field wind speed.

[0144] Step S404: Obtain the ratio change rate based on the ratio of the i-th background convection velocity to the reference wind speed and the ratio of the (i+1)-th background convection velocity to the reference wind speed.

[0145] In this embodiment, according to formula 13:

[0146]

[0147] The rate of change of the ratio m is obtained. Where H... i (x) represents the ratio of the i-th background convection velocity to the reference wind speed; H i+1 (x) represents the ratio of the background convection velocity to the reference wind speed at the (i+1)th epoch.

[0148] Step S405: If the rate of change of the ratio is less than a preset threshold, the ratio of the I background convection velocity to the reference wind speed is obtained.

[0149] In this embodiment, I represents the number of iterations.

[0150] In this embodiment, for example, the preset threshold is 1%.

[0151] In this embodiment, if the rate of change of the ratio is determined to be greater than or equal to a preset threshold, then step S401 is executed.

[0152] Step S406: Based on the distribution of background flow field wind speed, air field wind speed, thrust coefficient, turbulence intensity, and the ratio of the first background convection velocity to the reference wind speed, obtain the wake velocity deficit.

[0153] In this embodiment, the ratio H of the first background convection velocity to the reference wind speed is... I Substituting (x) into Formula 11, we obtain the wake velocity deficit.

[0154] In this embodiment, in any iteration, the ratio of the i-th background convective velocity to the reference wind speed is obtained; the i-th wake velocity deficit is obtained based on the background flow field wind speed, thrust coefficient, and the ratio of the i-th background convective velocity to the reference wind speed; the (i+1)-th background convective velocity to the reference wind speed is obtained based on the air field wind speed and the background flow field wind speed; the ratio change rate is obtained based on the ratios of the i-th and (i+1)-th background convective velocity to the reference wind speed; when the ratio change rate is determined to be less than a preset threshold, the I-th background convective velocity to the reference wind speed ratio is obtained; the wake velocity deficit is obtained based on the distribution of the background flow field wind speed, air field wind speed, thrust coefficient, turbulence intensity, and the I-th background convective velocity to the reference wind speed ratio; where I is the iteration number; the wake velocity deficit is obtained based on the distribution of the background flow field wind speed, air field wind speed, thrust coefficient, turbulence intensity, and the I-th background convective velocity to the reference wind speed ratio.

[0155] Figure 5This is a flowchart illustrating a fifth embodiment of a method for optimizing the layout of wind farms in nearshore areas, as provided in this application. Figure 5 As shown, the specific implementation of step S204 includes:

[0156] Step S501: Obtain the adjustment coefficient based on the distribution of turbulence intensity and the background wind speed.

[0157] In this embodiment, according to formula 14:

[0158]

[0159] Obtain the adjustment coefficient Among them, U b0 denoted as background wind speed; Iu represents the distribution of turbulence intensity.

[0160] Step S502: Obtain the corrected thrust coefficient based on the adjustment coefficient, background flow field wind speed, and wind turbine diameter.

[0161] In this embodiment, according to formula 15:

[0162]

[0163] Obtain the corrected thrust coefficient in, For adjustment coefficients; D is the rotor diameter; U b0 The background flow field wind speed.

[0164] In this embodiment, the adjustment coefficient is obtained based on the distribution of turbulence intensity and the background flow field wind speed; the corrected thrust coefficient is obtained based on the adjustment coefficient, the background flow field wind speed and the rotor diameter.

[0165] Figure 6 This is a flowchart illustrating a sixth embodiment of a method for optimizing the layout of wind farms in nearshore areas, as provided in this application. Figure 6 As shown, specifically, obtaining the cable cost in step S102 includes:

[0166] Step S601: Obtain the sum of squares of turbulence based on the additional turbulence intensity distribution and the background turbulence intensity.

[0167] Step S602: Obtain the distribution of turbulence intensity based on the sum of squares of turbulence.

[0168] In this embodiment, according to formula 16:

[0169]

[0170] The turbulence intensity distribution Iu is obtained. Where ΔIu is the additional turbulence intensity distribution; I b0 The background turbulence intensity.

[0171] In this embodiment, the sum of squares of turbulence is obtained based on the distribution of additional turbulence intensity and the turbulence intensity of the background flow field; the distribution of turbulence intensity is obtained based on the sum of squares of turbulence.

[0172] Figure 7 This is a flowchart illustrating Embodiment Seven of a method for optimizing the layout of wind farms in nearshore areas, provided as an embodiment of this application. Based on the above embodiments, as... Figure 7 As shown, one specific implementation of step S105 is as follows:

[0173] Step S701: In each round, obtain the population of the i-th wind farm unit.

[0174] Step S702: Obtain the i-th variant wind farm unit population based on the i-th wind farm unit population.

[0175] In this embodiment, the population of the i-th wind farm unit is mutated to obtain the i-th mutated wind farm unit population.

[0176] Step S703: Obtain the (i+1)th wind farm unit population based on the i-th variant wind farm unit population.

[0177] In this embodiment, the population of the i-th variant wind farm unit is screened to obtain the population of the (i+1)-th wind farm unit.

[0178] Step S704: When the total power generation is determined to be at its maximum value, the layout of the Nth wind farm units is obtained, and the optimization process is stopped.

[0179] In this embodiment, N represents the total number of wind farms, and the layout of the Nth wind farm turbines is the wind farm arrangement.

[0180] In this embodiment, if it is determined that the total power generation is not at its maximum value, step S701 is executed.

[0181] In this embodiment, in each round, the i-th wind farm turbine population is obtained; based on the i-th wind farm turbine population, the i-th variant wind farm turbine population is obtained; based on the i-th variant wind farm turbine population, the (i+1)-th wind farm turbine population is obtained; when the total power generation is determined to be the maximum value, the N-th wind farm turbine layout is obtained, and the optimization process is stopped; where N is the total number of rounds, and the N-th wind farm turbine layout is the wind farm arrangement.

[0182] It should be noted that although the steps in the above embodiments are described in a specific order, those skilled in the art will understand that in order to achieve the effect of this application, different steps do not necessarily have to be executed in such an order. They can be executed simultaneously (in parallel) or in other orders, and these variations are all within the scope of protection of this application.

[0183] Furthermore, this application also provides a device for optimizing the layout of wind farms in offshore areas.

[0184] Figure 8 This is a schematic diagram of a near-shore wind farm layout optimization device provided in an embodiment of this application. Figure 8 As shown, the apparatus in this embodiment mainly includes an acquisition module 11, an analysis module 12, a processing module 13, and an optimization module 14. In some embodiments, one or more of the acquisition module 11, analysis module 12, processing module 13, and optimization module 14 can be combined into a single module. In some embodiments, the acquisition module 11 can be configured to obtain the background wind speed and background turbulence intensity based on the wind resource data; the analysis module 12 can be configured to obtain the background wind speed and background turbulence intensity based on the wind resource data; the processing module 13 can be configured to obtain the initial population of wind farm units based on the wind farm construction area and the number of wind turbine units; wherein, the initial population of wind farm units includes the location coordinates of multiple wind turbine units; the processing module 13 can also be configured to obtain the total power generation based on the background wind speed and background turbulence intensity; the optimization module 14 can be configured to optimize the initial population of wind farm units based on the total power generation to obtain the wind farm unit layout.

[0185] The aforementioned offshore wind farm layout optimization device is used for execution Figure 1 The embodiments of the offshore wind farm layout optimization method shown are similar in technical principle, technical problem solved and technical effect. Those skilled in the art can clearly understand that, for the sake of convenience and brevity, the specific working process and related descriptions of the offshore wind farm layout optimization device can be found in the embodiments of the offshore wind farm layout optimization method, which will not be repeated here.

[0186] Those skilled in the art will understand that all or part of the processes in the method of the above-described embodiment can also be implemented by a computer program instructing related hardware. The computer program can be stored in a computer-readable storage medium, and when executed by a processor, it can implement the steps of the various method embodiments described above. The computer program includes computer program code, which can be in the form of source code, object code, executable file, or some intermediate form. The computer-readable storage medium can include any entity or device capable of carrying the computer program code, a medium, a USB flash drive, a portable hard drive, a magnetic disk, an optical disk, a computer memory, a read-only memory, a random access memory, an electrical carrier signal, a telecommunication signal, and a software distribution medium, etc. It should be noted that the content included in the computer-readable storage medium can be appropriately added or removed according to the requirements of legislation and patent practice in the jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, the computer-readable storage medium does not include electrical carrier signals and telecommunication signals.

[0187] Furthermore, this application also provides a device for optimizing the layout of wind farms in offshore areas.

[0188] Figure 9 This is a schematic diagram of an embodiment of a wind farm layout optimization device for nearshore areas, provided as an example of this application. Figure 9 As shown, the offshore wind farm layout optimization device includes at least one processor 21 and a memory 22. The memory 22 can be configured to store the execution of the above-mentioned... Figures 1 to 7 The program for the offshore wind farm layout optimization method of the illustrated embodiment includes a processor 21 configured to execute a program stored in a memory 22. This program includes, but is not limited to, a program executing an offshore wind farm layout optimization method according to the above-described method embodiment. For ease of explanation, only the parts relevant to the embodiments of this application are shown; for specific technical details not disclosed, please refer to the method section of the embodiments of this application. The offshore wind farm layout optimization device can be a control device comprising various electronic devices.

[0189] Furthermore, this application also provides a computer-readable storage medium. In one embodiment of the computer-readable storage medium according to this application, the computer-readable storage medium can be configured to store a program that executes the near-shore wind farm layout optimization method of the above-described method embodiments. This program can be loaded and run by a processor to implement the above-described near-shore wind farm layout optimization method. For ease of explanation, only the parts related to the embodiments of this application are shown; for specific technical details not disclosed, please refer to the method section of the embodiments of this application. The computer-readable storage medium can be a storage device device including various electronic devices. Optionally, in the embodiments of this application, the computer-readable storage medium is a non-transitory computer-readable storage medium.

[0190] Furthermore, it should be understood that since the various modules are only provided to illustrate the functional units of the device described in this application, the physical devices corresponding to these modules may be the processor itself, or a part of the processor's software, hardware, or a combination of both. Therefore, the number of modules shown in the figures is merely illustrative.

[0191] Those skilled in the art will understand that the various modules in the device can be adaptively split or combined. Such splitting or combining of specific modules will not cause the technical solution to deviate from the principles of this application; therefore, the technical solutions after splitting or combining will fall within the protection scope of this application.

[0192] The technical solutions of this application have been described above with reference to the preferred embodiments shown in the accompanying drawings. However, it will be readily understood by those skilled in the art that the scope of protection of this application is obviously not limited to these specific embodiments. Without departing from the principles of this application, those skilled in the art can make equivalent changes or substitutions to the relevant technical features, and the technical solutions after these changes or substitutions will all fall within the scope of protection of this application.

Claims

1. A method for optimizing the layout of wind farms in nearshore areas, characterized in that, include: Obtain data on wind farm construction areas, number of wind turbine units, and wind resources; Based on the wind resource data, the background wind speed and background turbulence intensity are obtained. Based on the wind farm construction area and the number of wind turbine units, an initial population of wind farm units is obtained; wherein, the initial population of wind farm units includes the location coordinates of multiple wind turbine units; The total power generation is obtained based on the background wind speed and the background turbulence intensity. Based on the total power generation, the initial population of the wind farm units is optimized to obtain the wind farm unit layout; The step of obtaining the total power generation based on the background wind speed and the background turbulence intensity includes: Based on the flow direction behind the wind turbine, the rotor diameter, and the turbulence intensity of the background flow field, the wake velocity deficit half-width and the standard deviation of the Gaussian distribution in the wake edge region of the wind turbine are obtained. The additional turbulence intensity distribution is obtained based on the wake velocity deficit half-width of the wind turbine, the standard deviation of the Gaussian distribution in the wake edge region, and the ground correction. The distribution of turbulence intensity is obtained based on the additional turbulence intensity distribution and the background flow field turbulence intensity; Based on the distribution of turbulence intensity, the corrected thrust coefficient is obtained; The wake velocity deficit is obtained based on the background flow field wind speed, air field wind speed, thrust coefficient, and the corrected thrust coefficient. Based on the aforementioned additional turbulence intensity distribution, the inflow additional flow-direction turbulence intensity is obtained; The inflow velocity loss is obtained based on the average velocity loss. The wind speed in front of the wheel hub is obtained based on the ambient incoming wind speed and the inflow velocity deficit. The current output power of the wind turbine is obtained based on the wind speed in front of the hub. The total output power is obtained based on the wind speed, the current output power of the wind turbine, the number of wind turbines, and wind resource data.

2. The method according to claim 1, characterized in that, Obtaining the ground correction includes: The correction factor is obtained based on the wake radius and wake half-width; The ground correction is obtained based on the correction coefficient and the correction amount.

3. The method according to claim 1, characterized in that, The step of obtaining the wake velocity deficit based on the background flow field wind speed, air field wind speed, thrust coefficient, and corrected thrust coefficient includes: In any iteration, obtain the ratio of the i-th background convection velocity to the reference wind speed; The i-th wake velocity deficit is obtained based on the background flow field wind speed, thrust coefficient, corrected thrust coefficient, and the ratio of the i-th background convection velocity to the reference wind speed. Based on the air field wind speed and the background flow field wind speed, the ratio of the (i+1)th background convection velocity to the reference wind speed is obtained; The ratio change rate is obtained based on the ratio of the i-th background convection velocity to the reference wind speed and the ratio of the (i+1)-th background convection velocity to the reference wind speed. Once the rate of change of the ratio is determined to be less than a preset threshold, the ratio of the I-th background convection velocity to the reference wind speed is obtained; where I is the iteration number. The wake velocity deficit is obtained based on the background flow field wind speed, air field wind speed, thrust coefficient, the distribution of turbulence intensity, and the ratio of the first background convection velocity to the reference wind speed.

4. The method according to claim 1, characterized in that, The step of obtaining the corrected thrust coefficient based on the distribution of turbulence intensity includes: The adjustment coefficient is obtained based on the distribution of turbulence intensity and the background wind speed. The corrected thrust coefficient is obtained based on the adjustment coefficient, the background flow field wind speed, and the rotor diameter.

5. The method according to claim 1, characterized in that, The step of obtaining the turbulence intensity distribution based on the additional turbulence intensity distribution and the background flow field turbulence intensity includes: Based on the additional turbulence intensity distribution and the background flow field turbulence intensity, the sum of squares of turbulence is obtained; The distribution of turbulence intensity is obtained based on the sum of squares of the turbulence.

6. The method according to claim 1, characterized in that, The optimization of the initial population of wind farm units based on the total power generation to obtain the wind farm layout includes: In each round, obtain the population of wind farm units for the i-th wind farm; Based on the i-th wind farm unit population, the i-th variant wind farm unit population is obtained; Based on the i-th variant wind farm unit population, the (i+1)-th wind farm unit population is obtained; When the total power generation is determined to be the maximum value, the layout of the Nth wind farm unit is obtained, and the optimization process is stopped; where N is the total number of cycles, and the layout of the Nth wind farm unit is the wind farm arrangement.

7. A device for optimizing the layout of wind farms in nearshore areas, characterized in that, include: The acquisition module is used to acquire data on wind farm construction areas, the number of wind turbine units, and wind resources. The analysis module is used to obtain the background wind speed and background turbulence intensity based on the wind resource data. The processing module is used to obtain an initial population of wind farm units based on the wind farm construction area and the number of wind turbine units; wherein, the initial population of wind farm units includes the location coordinates of multiple wind turbine units; The processing module is also used to obtain the total power generation based on the background wind speed and the background turbulence intensity. An optimization module is used to optimize the initial population of wind farm turbines based on the total power generation to obtain the wind farm turbine layout. The step of obtaining the total power generation based on the background wind speed and the background turbulence intensity includes: Based on the flow direction behind the wind turbine, the rotor diameter, and the turbulence intensity of the background flow field, the wake velocity deficit half-width and the standard deviation of the Gaussian distribution in the wake edge region of the wind turbine are obtained. The additional turbulence intensity distribution is obtained based on the wake velocity deficit half-width of the wind turbine, the standard deviation of the Gaussian distribution in the wake edge region, and the ground correction. The distribution of turbulence intensity is obtained based on the additional turbulence intensity distribution and the background flow field turbulence intensity; Based on the distribution of turbulence intensity, the corrected thrust coefficient is obtained; The wake velocity deficit is obtained based on the background flow field wind speed, air field wind speed, thrust coefficient, and the corrected thrust coefficient. Based on the aforementioned additional turbulence intensity distribution, the inflow additional flow-direction turbulence intensity is obtained; The inflow velocity loss is obtained based on the average velocity loss. The wind speed in front of the wheel hub is obtained based on the ambient incoming wind speed and the inflow velocity deficit. The current output power of the wind turbine is obtained based on the wind speed in front of the hub. The total output power is obtained based on the wind speed, the current output power of the wind turbine, the number of wind turbines, and wind resource data.

8. A device for optimizing the layout of wind farms in nearshore areas, comprising a processor and a storage device, wherein the storage device is adapted to store multiple lines of program code, characterized in that, The program code is adapted to be loaded and run by the processor to perform the method of any one of claims 1 to 6.

9. A computer-readable storage medium storing a plurality of program codes, characterized in that, The program code is adapted to be loaded and run by a processor to perform the method of any one of claims 1 to 6.

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