A method and device for estimating wind power resource potential based on geographical conditions

Abstract

The present application discloses a method and device for estimating wind power resource potential based on geographical conditions. The method includes: performing wind speed characteristic analysis based on preset GEOS‑FP meteorological data, and calculating the wind speed at the hub height of the wind turbine to obtain the hub wind speed; obtaining the actual generated power of the wind turbine based on the hub wind speed and a preset power wind speed curve, wherein the preset power wind speed curve is a mapping relationship between generated power and wind speed; after calculating the capacity factor based on the actual generated power of the wind turbine, estimating the wind turbine potential based on preset natural geographical condition constraints, the capacity factor, and preset wind power resource constraints; the preset natural geographical condition constraints include land terrain constraints, offshore sea area constraints, and average annual utilization time constraints, and the wind turbine potential includes wind turbine installed capacity potential and wind turbine power generation potential. The present application can solve the technical problem that the existing technical analysis process lacks pertinence, resulting in a lack of reliability and accuracy in resource assessment results.

Description

Technical Field

[0001] The present application relates to the field of wind power generation technology, and in particular to a method and device for estimating wind power resource potential based on geographical conditions. Background Art

[0002] As the energy crisis and global warming become increasingly prominent, energy conservation, emission reduction, and the vigorous development of renewable energy have become challenges we must overcome. Wind power systems primarily rely on wind resources for power generation, but the site selection of wind farms and the uncertainty of wind speed are both challenges that must be overcome.

[0003] In the coordinated optimization of new power systems, where power generation costs and system stability are continuously optimized, accurate generation resource assessment has a direct impact on the coordinated and optimized operation of the entire power plant system. However, existing resource assessment methods lack specificity, resulting in unreliable and inaccurate results. Summary of the Invention

[0004] The present application provides a method and device for estimating wind power resource potential based on geographical conditions, which is used to solve the technical problem that the existing technical analysis process lacks pertinence, resulting in a lack of reliability and accuracy in resource assessment results.

[0005] In view of this, the first aspect of the present application provides a method for estimating wind power resource potential based on geographical conditions, comprising:

[0006] Based on the preset GEOS-FP meteorological data, the wind speed characteristics are analyzed and the wind speed at the hub height of the wind turbine is calculated to obtain the hub wind speed;

[0007] Obtaining the actual generated power of the wind turbine according to the hub wind speed and the preset power wind speed curve, wherein the preset power wind speed curve is a mapping relationship between generated power and wind speed;

[0008] After calculating the capacity factor based on the actual power generation of the wind turbine, estimating the potential of the wind turbine based on preset natural geographical conditions, the capacity factor and preset wind power resource constraints;

[0009] The preset natural geographical condition constraints include land terrain constraints, offshore sea area constraints and annual average utilization time constraints, and the wind turbine potential includes wind turbine installation potential and wind turbine power generation potential.

[0010] Preferably, the wind speed characteristic analysis based on preset GEOS-FP meteorological data and calculating the wind speed at the wind turbine hub height to obtain the hub wind speed includes:

[0011] Analyze wind speed characteristics based on pre-set GEOS-FP meteorological data and determine the wind speed correlation between wind speed, temperature, air pressure and ground height;

[0012] The wind speed at the hub height of the wind turbine is calculated using a power-law wind speed contour line model and a reference height wind speed to obtain the hub wind speed. The reference height wind speed is obtained based on the wind speed correlation relationship.

[0013] Preferably, the wind speed characteristic analysis is performed based on the preset GEOS-FP meteorological data, and the wind speed at the wind turbine hub height is calculated to obtain the hub wind speed, and then the method further includes:

[0014] Performing a downscaling deviation correction operation on the hub wind speed using historical height wind speed;

[0015] The hub wind speed is standardized and converted based on the air temperature and air pressure corresponding to the wind turbine hub height.

[0016] Preferably, the step of obtaining the actual generated power of the wind turbine according to the hub wind speed and the preset power wind speed curve further includes:

[0017] The actual generated power of the wind turbine is corrected based on the preset wind turbine output loss parameters.

[0018] Preferably, after calculating the capacity factor based on the actual power generation of the wind turbine, estimating the potential of the wind turbine based on preset natural geographical conditions, the capacity factor and preset wind power resource constraints includes:

[0019] Calculating the actual power generation of the wind farm within a preset time period based on the actual power generation of the wind turbine;

[0020] Calculating the ratio of the actual power generation of the wind farm to the maximum power generation of the wind farm to obtain a capacity factor;

[0021] Configuring land terrain constraints and sea area offshore constraints according to land terrain features and sea area offshore distances respectively, and constructing preset natural geographical condition constraints based on the land terrain constraints, the sea area offshore constraints, and the annual average utilization time constraints;

[0022] The wind turbine installation potential and wind turbine power generation potential are estimated respectively according to the preset natural geographical condition constraints, the capacity factor and the preset wind power resource constraints.

[0023] Preferably, after calculating the capacity factor based on the actual power generation of the wind turbine, estimating the potential of the wind turbine based on preset natural geographical conditions, the capacity factor and preset wind power resource constraints, further comprising:

[0024] Qualified new energy sites are screened based on the wind turbine potential and wind turbine power generation utilization time.

[0025] A second aspect of the present application provides a device for estimating wind power resource potential based on geographical conditions, comprising:

[0026] The wind speed calculation module is used to analyze wind speed characteristics based on the preset GEOS-FP meteorological data, and calculate the wind speed at the hub height of the wind turbine to obtain the hub wind speed;

[0027] A power acquisition module, configured to acquire the actual generated power of the wind turbine according to the hub wind speed and a preset power wind speed curve, wherein the preset power wind speed curve is a mapping relationship between generated power and wind speed;

[0028] A potential estimation module is configured to calculate a capacity factor based on the actual power generation of the wind turbine and then estimate the potential of the wind turbine based on preset natural geographical conditions, the capacity factor, and preset wind power resource constraints;

[0029] The preset natural geographical condition constraints include land terrain constraints, offshore sea area constraints and annual average utilization time constraints, and the wind turbine potential includes wind turbine installation potential and wind turbine power generation potential.

[0030] Preferably, the wind speed calculation module is specifically used to:

[0031] Analyze wind speed characteristics based on pre-set GEOS-FP meteorological data and determine the wind speed correlation between wind speed, temperature, air pressure and ground height;

[0032] The wind speed at the hub height of the wind turbine is calculated using a power-law wind speed contour line model and a reference height wind speed to obtain the hub wind speed. The reference height wind speed is obtained based on the wind speed correlation relationship.

[0033] Preferably, it also includes:

[0034] a deviation correction module, configured to perform a downscaling deviation correction operation on the hub wind speed using historical height wind speeds;

[0035] The standard conversion module is used to perform a standard conversion operation on the hub wind speed based on the air temperature and air pressure corresponding to the height of the wind turbine hub.

[0036] Preferably, the potential estimation module is specifically used to:

[0037] Calculating the actual power generation of the wind farm within a preset time period based on the actual power generation of the wind turbine;

[0038] Calculating the ratio of the actual power generation of the wind farm to the maximum power generation of the wind farm to obtain a capacity factor;

[0039] Configuring land terrain constraints and sea area offshore constraints according to land terrain features and sea area offshore distances respectively, and constructing preset natural geographical condition constraints based on the land terrain constraints, the sea area offshore constraints, and the annual average utilization time constraints;

[0040] The wind turbine installation potential and wind turbine power generation potential are estimated respectively according to the preset natural geographical condition constraints, the capacity factor and the preset wind power resource constraints.

[0041] It can be seen from the above technical solutions that the embodiments of the present application have the following advantages:

[0042] In the present application, a method for estimating wind power resource potential based on geographical conditions is provided, comprising: performing wind speed characteristic analysis based on preset GEOS-FP meteorological data, and calculating the wind speed at the hub height of the wind turbine to obtain the hub wind speed; obtaining the actual generated power of the wind turbine according to the hub wind speed and a preset power wind speed curve, wherein the preset power wind speed curve is a mapping relationship between generated power and wind speed; after calculating the capacity factor based on the actual generated power of the wind turbine, estimating the wind turbine potential according to preset natural geographical condition constraints, the capacity factor and preset wind power resource constraints; the preset natural geographical condition constraints include land terrain constraints, offshore sea area constraints and average annual utilization time constraints, and the wind turbine potential includes wind turbine installed capacity potential and wind turbine power generation potential.

[0043] The geographically-based wind power resource potential estimation method provided in this application analyzes the characteristics of wind speed from meteorological data and uses the wind speed at the hub height of the wind turbine to obtain the actual power generated by the generator, thereby calculating a more targeted capacity factor. When estimating the potential, it not only considers the constraints of wind power resources, but also the impact of different geographical conditions, that is, pre-setting natural geographical conditions constraints. This makes the wind power potential estimation results more consistent with actual conditions and more accurate and reliable. Therefore, this application can solve the technical problem that the existing technical analysis process lacks specificity, resulting in a lack of reliability and accuracy in resource assessment results. BRIEF DESCRIPTION OF THE DRAWINGS

[0044] Figure 1 A flowchart of a method for estimating wind power resource potential based on geographical conditions provided in an embodiment of the present application;

[0045] Figure 2 A schematic diagram of the structure of a device for estimating wind power resource potential based on geographical conditions provided in an embodiment of the present application;

[0046] Figure 3 This is a preset power wind speed curve diagram provided in an embodiment of the present application. DETAILED DESCRIPTION

[0047] In order to help those skilled in the art better understand the present invention, the following will clearly and completely describe the technical solutions in the embodiments of the present invention in conjunction with the accompanying drawings. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative work are within the scope of protection of this application.

[0048] For easier understanding, see Figure 1 , the present application provides an embodiment of a method for estimating wind power resource potential based on geographical conditions, comprising:

[0049] Step 101: Analyze wind speed characteristics based on preset GEOS-FP meteorological data, calculate the wind speed at the hub height of the wind turbine, and obtain the hub wind speed.

[0050] Furthermore, step 101 includes:

[0051] Analyze wind speed characteristics based on pre-set GEOS-FP meteorological data and determine the wind speed correlation between wind speed, temperature, air pressure and ground height;

[0052] The power-law wind speed contour line model and the reference height wind speed are used to calculate the wind speed at the hub height of the wind turbine to obtain the hub wind speed. The reference height wind speed is obtained based on the wind speed correlation relationship.

[0053] The GEOS-FP meteorological data is derived from the GEOS-5 model, which is a high-resolution global climate model developed using the Goddard Earth Observing System model developed by NASA. It combines field observation data with mathematical models to achieve high-precision climate forecasts. The wind speed characteristic analysis process mainly involves obtaining different spatial resolutions of wind speed data, such as 0.3125° longitude × 0.25° latitude; the latitude area is roughly equivalent to 31.25km × 25km, and the time resolution is hourly. This embodiment ultimately determined that hourly wind speed at a height of 10m above the ground, wind speed at a height of 50m above the ground, as well as temperature, air pressure and other data were obtained over a five-year period, and a wind speed correlation analysis was performed to determine the correlation between the various factors, which was recorded as a wind speed correlation relationship.

[0054] The wind speed at the hub height of the wind turbine can be calculated using the power law wind speed contour model and the reference height wind speed as follows:

[0055]

[0056] Wherein, z is the height of the wind turbine hub. In this embodiment, z=100m, z 50 The reference height is 50m, V(z) is the wind speed at the hub height of the wind turbine, hub wind speed, V50 is the wind speed at a reference height of 50 m, and α is the wind shear coefficient, whose value depends on the stratification stability and surface roughness.

[0057] Furthermore, step 101 further includes:

[0058] Use historical height wind speed to perform downscaling deviation correction on hub wind speed;

[0059] The hub wind speed is standardized and converted based on the air temperature and pressure corresponding to the hub height of the wind turbine.

[0060] Historical height wind speeds are the multi-year average wind speeds at 100 meters from the Global Wind Atlas (GWA) 3.0, with a spatial accuracy of 0.0025° longitude by 0.0025° latitude. The corrected hub wind speed data maintains high temporal accuracy while also ensuring high spatial accuracy for the GWA data. To increase temporal and spatial resolution, output can be configured with a spatial resolution of 0.0625° longitude by 0.0625° latitude.

[0061] In order to facilitate subsequent data analysis, the hub wind speed needs to be converted to the wind speed under standard conditions. The conversion process can be expressed as:

[0062]

[0063] Among them, V original 、V corrected are the hub wind speed and the standardized hub wind speed, respectively. P and T represent the air pressure and air temperature at the height of the wind turbine hub, respectively, which can be obtained through GEOS-FP meteorological data. R is the atmospheric gas constant, which is 287.05 N·m / (kg·K) for dry air.

[0064] Step 102: Obtain the actual generated power of the wind turbine according to the hub wind speed and the preset power wind speed curve. The preset power wind speed curve is a mapping relationship between generated power and wind speed.

[0065] See also Figure 3 , is an example of a wind turbine given in this embodiment, in which GE 2.5MW wind turbine and Vestas 8.0MW wind turbine are selected, and the wind energy potential of these wind turbines in different geographical environments is studied; Figure 3 The horizontal axis is the wind speed value, and the vertical axis is the power generation value. The curve is used to describe the mapping relationship between wind speed and power generation. It should be noted that the research and analysis height selected in this embodiment is 100m.

[0066] Furthermore, step 102 further includes:

[0067] The actual power generation of the wind turbine is corrected based on the preset wind turbine output loss parameters.

[0068] In an actual wind farm, the wind turbines may affect each other's operating conditions due to airflow interference, resulting in output power loss. In order to ensure the accuracy of the actual generated power of the wind turbine, correction parameters can be used to perform power correction. In this embodiment, the average loss rate of the wind turbine output power is set to 10%. This can be used as a preset wind turbine output loss parameter to correct the actual generated power of the wind turbine. That is, removing the loss will make it closer to the actual generated power. The corrected generated power is then 90% of the originally calculated power.

[0069] Step 103: After calculating the capacity factor based on the actual power generation of the wind turbine, the wind turbine potential is estimated based on the preset natural geographical condition constraints, the capacity factor, and the preset wind power resource constraints.

[0070] The preset natural geographical condition constraints include land terrain constraints, offshore sea area constraints and annual average utilization time constraints, and the wind turbine potential includes wind turbine installation potential and wind turbine power generation potential.

[0071] Furthermore, step 103 includes:

[0072] Calculate the actual power generation of the wind farm within a preset time period based on the actual power generation of the wind turbine;

[0073] Calculate the ratio between the actual power generation of the wind farm and the maximum power generation of the wind farm to obtain the capacity factor;

[0074] Configure land terrain constraints and sea offshore constraints based on the land terrain characteristics and the offshore distance of the sea area respectively, and build preset natural geographical condition constraints based on the land terrain constraints, sea offshore constraints and annual average utilization time constraints;

[0075] The wind turbine installed capacity potential and wind turbine power generation potential are estimated respectively based on the preset natural geographical conditions constraints, capacity factor and preset wind power resource constraints.

[0076] The preset time period can be configured according to actual conditions and is not limited here. The capacity factor CF is defined as the ratio between the actual power generation of the wind farm and the maximum power generation over a period of time, which can be expressed as:

[0077]

[0078] Among them, G is the actual power generation of the wind farm, which is calculated based on the actual power generation of the wind turbine; G max is the maximum power generation of the wind farm.

[0079] In order to select areas suitable for wind farm development, geographical constraints must be considered when calculating wind power installed capacity potential and power generation potential, that is, pre-setting natural geographical constraints. For onshore wind power development, this embodiment excludes areas with restricted wind power development based on the land use type dataset of the Moderate-resolution Imaging Spectroradiometer (MODIS), including forests, water bodies, areas permanently covered by snow or glaciers, as well as cities and developed areas. At the same time, referring to the land terrain data of the Global Digital Elevation Model, areas with slopes greater than 20% are excluded. For offshore wind power potential calculations, suitable development areas are limited to offshore waters with an offshore distance of not less than 10 kilometers and not more than 80 kilometers and a water depth of 50 meters.

[0080] In addition, the annual average utilization time constraint excludes areas with an annual average utilization of less than 1,800 hours (the reasonable annual average utilization hours for Class IV resource areas, with an average capacity factor of approximately 20.5%) from the calculation of onshore wind power installed capacity and power generation potential, and excludes areas with an annual average utilization of less than 2,600 hours (the reasonable annual average utilization hours for offshore wind power projects, with an average capacity factor of approximately 29.7%) from the calculation of offshore wind power installed capacity and power generation potential. Based on the layout of wind turbines in existing wind power development projects and wind farm planning, the installed capacity density per unit area of ​​onshore wind power development is taken as 3MW / km 2 The installed capacity density per unit area of ​​offshore wind power development is 6MW / km 2 Whether it is land or sea, the corresponding wind turbine potential can be calculated based on the constraints.

[0081] The process of estimating wind turbine installed capacity potential and wind turbine power generation potential can be expressed as:

[0082] CP=Σ(Area i ×LUR i ×D max )

[0083] GP=Σ(Area i ×LUR i ×D max ×CF i ×Hour)

[0084] Among them, CP and GP are wind turbine installed capacity potential and wind turbine power generation potential respectively, CF i is the average capacity factor of grid i over many years, Area i For this example, the area of ​​grid i is selected, LUR iis the land utilization rate suitable for wind power development in grid i, and its value comprehensively considers the preset natural geographical conditions and preset wind power resource constraints in the grid; D max is the maximum installation density of wind turbines, and Hour is the number of hours in a year. In this embodiment, the value is 8760 hours.

[0085] Furthermore, step 103 further includes:

[0086] Qualified new energy sites are selected based on wind turbine potential and wind turbine power generation utilization time.

[0087] In addition to screening qualified new energy sites, the estimated wind turbine potential can also be used to correct the wind power installed capacity and power generation potential suitable for development in each region. The specific process is not described in detail here.

[0088] The embodiment of the present application provides a method for estimating wind power resource potential based on geographical conditions. This method analyzes the characteristics of wind speed from meteorological data and uses the wind speed at the hub height of the wind turbine to obtain the actual power generated by the generator, thereby calculating a more targeted capacity factor. When performing potential estimation, it not only considers wind power resource constraints, but also the impact of different geographical conditions, that is, pre-setting natural geographical condition constraints. This makes the wind power potential estimation results more consistent with actual conditions and more accurate and reliable. Therefore, the embodiment of the present application can solve the technical problem that the existing technical analysis process lacks specificity, resulting in a lack of reliability and accuracy in resource assessment results.

[0089] For easier understanding, see Figure 2 The present application also provides an embodiment of a device for estimating wind power resource potential based on geographical conditions, comprising:

[0090] The wind speed calculation module 201 is used to analyze the wind speed characteristics based on the preset GEOS-FP meteorological data, and calculate the wind speed at the hub height of the wind turbine to obtain the hub wind speed;

[0091] The power acquisition module 202 is used to obtain the actual generated power of the wind turbine according to the hub wind speed and the preset power wind speed curve, where the preset power wind speed curve is a mapping relationship between generated power and wind speed;

[0092] A potential estimation module 203 is configured to calculate the capacity factor based on the actual power generation of the wind turbine and then estimate the potential of the wind turbine based on preset natural geographical constraints, the capacity factor, and preset wind power resource constraints;

[0093] The preset natural geographical condition constraints include land terrain constraints, offshore sea area constraints and annual average utilization time constraints, and the wind turbine potential includes wind turbine installation potential and wind turbine power generation potential.

[0094] Furthermore, the wind speed calculation module 201 is specifically configured to:

[0095] Analyze wind speed characteristics based on pre-set GEOS-FP meteorological data and determine the wind speed correlation between wind speed, temperature, air pressure and ground height;

[0096] The power-law wind speed contour line model and the reference height wind speed are used to calculate the wind speed at the hub height of the wind turbine to obtain the hub wind speed. The reference height wind speed is obtained based on the wind speed correlation relationship.

[0097] Furthermore, it also includes:

[0098] The deviation correction module 204 is used to perform a downscaling deviation correction operation on the hub wind speed using the historical height wind speed;

[0099] The standard conversion module 205 is used to perform a standard conversion operation on the hub wind speed based on the air temperature and air pressure corresponding to the wind turbine hub height.

[0100] Furthermore, the potential estimation module 203 is specifically configured to:

[0101] Calculate the actual power generation of the wind farm within a preset time period based on the actual power generation of the wind turbine;

[0102] Calculate the ratio between the actual power generation of the wind farm and the maximum power generation of the wind farm to obtain the capacity factor;

[0103] Configure land terrain constraints and sea offshore constraints based on the land terrain characteristics and the offshore distance of the sea area respectively, and build preset natural geographical condition constraints based on the land terrain constraints, sea offshore constraints and annual average utilization time constraints;

[0104] The wind turbine installed capacity potential and wind turbine power generation potential are estimated respectively based on the preset natural geographical conditions constraints, capacity factor and preset wind power resource constraints.

[0105] In the several embodiments provided in this application, it should be understood that the disclosed devices and methods can be implemented in other ways. For example, the device embodiments described above are merely schematic. For example, the division of the units is merely a logical function division. In actual implementation, there may be other division methods, such as multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the mutual coupling or direct coupling or communication connection shown or discussed can be through some interfaces, indirect coupling or communication connection of devices or units, which can be electrical, mechanical or other forms.

[0106] The units described as separate components may or may not be physically separate, and the components shown as units may or may not be physical units, that is, they may be located in one place or distributed across multiple network units. Some or all of these units may be selected to achieve the purpose of this embodiment according to actual needs.

[0107] In addition, the functional units in the various embodiments of the present application may be integrated into a single processing unit, or each unit may exist physically separately, or two or more units may be integrated into a single unit. The aforementioned integrated units may be implemented in the form of hardware or software functional units.

[0108] If the integrated unit is implemented in the form of a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present application is essentially or the part that contributes to the prior art or all or part of the technical solution can be embodied in the form of a software product. The computer software product is stored in a storage medium and includes a number of instructions for executing all or part of the steps of the method described in each embodiment of the present application through a computer device (which can be a personal computer, server, or network device, etc.). The aforementioned storage medium includes: U disk, mobile hard disk, read-only memory (English full name: Read-Only Memory, English abbreviation: ROM), random access memory (English full name: Random Access Memory, English abbreviation: RAM), disk or optical disk and other media that can store program code.

[0109] As described above, the above embodiments are only used to illustrate the technical solutions of the present application, rather than to limit them. Although the present application has been described in detail with reference to the above embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the above embodiments, or make equivalent replacements for some of the technical features therein. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present application.

Claims

1. A method for estimating wind power resource potential based on geographical conditions, characterized in that: include: Based on the preset GEOS-FP meteorological data, the wind speed characteristics are analyzed and the wind speed at the hub height of the wind turbine is calculated to obtain the hub wind speed. The specific process is as follows: Analyze wind speed characteristics based on pre-set GEOS-FP meteorological data and determine the wind speed correlation between wind speed, temperature, air pressure and ground height; Calculating the wind speed at the hub height of the wind turbine using a power-law wind speed contour line model and a reference height wind speed to obtain the hub wind speed, wherein the reference height wind speed is obtained based on the wind speed correlation relationship; Obtaining the actual generated power of the wind turbine according to the hub wind speed and the preset power wind speed curve, wherein the preset power wind speed curve is a mapping relationship between generated power and wind speed; After calculating the capacity factor based on the actual power generation of the wind turbine, the wind turbine potential is estimated based on the preset natural geographical conditions, the capacity factor, and the preset wind power resource constraints. The specific process is as follows: Calculating the actual power generation of the wind farm within a preset time period based on the actual power generation of the wind turbine; Calculating the ratio of the actual power generation of the wind farm to the maximum power generation of the wind farm to obtain a capacity factor; Configuring land terrain constraints and sea area offshore constraints according to land terrain features and sea area offshore distances respectively, and constructing preset natural geographical condition constraints based on the land terrain constraints, the sea area offshore constraints, and the annual average utilization time constraints; respectively estimating the wind turbine installed capacity potential and the wind turbine power generation potential according to the preset natural geographical condition constraints, the capacity factor and the preset wind power resource constraints; The preset natural geographical condition constraints include land terrain constraints, offshore sea area constraints and annual average utilization time constraints, and the wind turbine potential includes wind turbine installation potential and wind turbine power generation potential.

2. The method for estimating wind power resource potential based on geographical conditions according to claim 1, characterized in that: The wind speed characteristic analysis is performed based on the preset GEOS-FP meteorological data, and the wind speed at the wind turbine hub height is calculated to obtain the hub wind speed, which then includes: Performing a downscaling deviation correction operation on the hub wind speed using historical height wind speed; The hub wind speed is standardized and converted based on the air temperature and air pressure corresponding to the wind turbine hub height.

3. The method for estimating wind power resource potential based on geographical conditions according to claim 1, characterized in that: The method further comprises: obtaining the actual generated power of the wind turbine according to the hub wind speed and the preset power wind speed curve; The actual generated power of the wind turbine is corrected based on the preset wind turbine output loss parameters.

4. The method for estimating wind power resource potential based on geographical conditions according to claim 1, characterized in that: After calculating the capacity factor based on the actual power generation of the wind turbine, estimating the potential of the wind turbine based on preset natural geographical conditions, the capacity factor and preset wind power resource constraints, further comprising: Qualified new energy sites are screened based on the wind turbine potential and wind turbine power generation utilization time.

5. A device for estimating wind power resource potential based on geographical conditions, characterized in that: include: The wind speed calculation module is used to analyze wind speed characteristics based on preset GEOS-FP meteorological data and calculate the wind speed at the hub height of the wind turbine to obtain the hub wind speed. The wind speed calculation module is specifically used to: Analyze wind speed characteristics based on pre-set GEOS-FP meteorological data and determine the wind speed correlation between wind speed, temperature, air pressure and ground height; Calculating the wind speed at the hub height of the wind turbine using a power-law wind speed contour line model and a reference height wind speed to obtain the hub wind speed, wherein the reference height wind speed is obtained based on the wind speed correlation relationship; A power acquisition module, configured to acquire the actual generated power of the wind turbine according to the hub wind speed and a preset power wind speed curve, wherein the preset power wind speed curve is a mapping relationship between generated power and wind speed; A potential estimation module is configured to calculate the capacity factor based on the actual power generation of the wind turbine and then estimate the potential of the wind turbine based on preset natural geographical conditions, the capacity factor, and preset wind power resource constraints. The potential estimation module is specifically configured to: Calculating the actual power generation of the wind farm within a preset time period based on the actual power generation of the wind turbine; Calculating the ratio of the actual power generation of the wind farm to the maximum power generation of the wind farm to obtain a capacity factor; Configuring land terrain constraints and sea area offshore constraints according to land terrain features and sea area offshore distances respectively, and constructing preset natural geographical condition constraints based on the land terrain constraints, the sea area offshore constraints, and the annual average utilization time constraints; respectively estimating the wind turbine installed capacity potential and the wind turbine power generation potential according to the preset natural geographical condition constraints, the capacity factor and the preset wind power resource constraints; The preset natural geographical condition constraints include land terrain constraints, offshore sea area constraints and annual average utilization time constraints, and the wind turbine potential includes wind turbine installation potential and wind turbine power generation potential.

6. The device for estimating wind power resource potential based on geographical conditions according to claim 5, characterized in that: Also includes: a deviation correction module, configured to perform a downscaling deviation correction operation on the hub wind speed using historical height wind speeds; The standard conversion module is used to perform a standard conversion operation on the hub wind speed based on the air temperature and air pressure corresponding to the height of the wind turbine hub.

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