A method, device, equipment and storage medium for determining the irradiation amount of a photovoltaic module

Abstract

The present application discloses a method, device, equipment and storage medium for determining the irradiation of a photovoltaic module, and relates to the technical field of photovoltaic power station design, including: calculating the direction vector of sunlight; determining the obstructions in the installation area of ​​a virtual photovoltaic module, and determining the shadow area cast by the obstructions on the virtual photovoltaic module; determining the inclination angle between the virtual photovoltaic module and the ground and the azimuth angle between the virtual photovoltaic module and the direction vector of sunlight, and determining the irradiation loss coefficient corresponding to the virtual photovoltaic module using the geographical location information, the inclination angle and the azimuth angle; obtaining the total irradiation of the horizontal plane within a unit time, and determining the annual comprehensive irradiation of the virtual photovoltaic module according to the total irradiation, the irradiation loss coefficient and the shadow area, so as to determine the installation position of the target photovoltaic module according to the annual comprehensive irradiation. By using the shadow area of ​​the sunlight direction vector and the irradiation loss coefficient, the annual irradiation of the photovoltaic module is obtained, so that the installation position of the photovoltaic module can be determined according to the irradiation.

Description

Technical Field

[0001] The present invention relates to the technical field of photovoltaic power station design, and in particular to a method, device, equipment and storage medium for determining the irradiation amount of a photovoltaic module. Background Art

[0002] Shadows have a significant impact on the power generation of photovoltaic modules. When a photovoltaic module is partially shaded, even if only the edge of the module is slightly shaded, its output power will be reduced by 10% - 30%. This is because the shaded area cannot receive light normally, resulting in a reduction in the overall power generation of the module. In severe shading, if more than half of the module area is shaded, the output power may be reduced by 50% or even more. If it is completely shaded, it will be almost impossible to generate electricity.

[0003] At present, the traditional method of solving shadow shading mainly involves on-site inspection to avoid the components being blocked by surrounding objects as much as possible, or by installing a tracking system so that the photovoltaic components can adjust their direction as the sun angle changes. However, this method is costly and may be limited in complex environments. Although these traditional methods can alleviate the shadow shading problem to a certain extent, they are often only carried out at a specific time point and can only obtain the shadow situation at that moment, or shadow analysis in the short term. It is difficult to comprehensively consider the complex shadow changes caused by the changes in the sun's position in different seasons throughout the year, which may lead to serious shadow shading problems in the subsequent component layout during certain periods of time, and further improvement and innovation are needed. Summary of the invention

[0004] In view of this, the purpose of the present invention is to provide a method, device, equipment and storage medium for determining the irradiation of photovoltaic modules, which can accurately obtain the comprehensive irradiation of photovoltaic modules in a year by accurately calculating the direction vector of sunlight throughout the year, the irradiation loss rate of photovoltaic modules and the area of ​​shadow areas on photovoltaic modules, thereby solving the problem of inaccurate comprehensive irradiation obtained by only analyzing the shadow area on photovoltaic modules within a specific time. The specific scheme is as follows:

[0005] In a first aspect, the present application provides a method for determining the irradiance of a photovoltaic module, comprising:

[0006] Acquire geographic location information of a target area, and calculate a sunlight direction vector corresponding to the target area throughout the year based on the geographic location information;

[0007] Determine the obstructions within the installation area of ​​the virtual photovoltaic components in the preset photovoltaic power station model according to the preset photovoltaic power station model in the target area, determine the projection point of the obstruction on any virtual photovoltaic component using the sunlight direction vector and the type of the obstruction, and determine the shadow area cast by the obstruction on the any virtual photovoltaic component based on the projection point and the target shadow calculation method;

[0008] Determine the inclination angle between the virtual photovoltaic assembly and the ground and the azimuth angle between the virtual photovoltaic assembly and the sunlight direction vector, and determine the radiation loss coefficient corresponding to the virtual photovoltaic assembly using the geographical location information, the inclination angle and the azimuth angle;

[0009] The total irradiance of the horizontal plane per unit time is obtained from a preset meteorological data platform, and the annual comprehensive irradiance of the virtual photovoltaic component is determined according to the total irradiance, the irradiance loss coefficient and the shadow area, so as to determine the installation position of the target photovoltaic component according to the annual comprehensive irradiance.

[0010] Optionally, the calculating, based on the geographical location information, a sunlight direction vector corresponding to the target area throughout the year includes:

[0011] Constructing a target three-dimensional rectangular coordinate system, and acquiring a solar azimuth angle and a solar altitude angle according to the target three-dimensional rectangular coordinate system and the geographical location information; wherein the solar azimuth angle is the angle between the projection of the sun's rays on the horizontal plane of the target area and the meridian of the target area, and the solar altitude angle is the angle between the sun's rays and the horizontal plane of the target area;

[0012] The sunlight direction vector corresponding to the target area throughout the year is calculated according to the geographical location information, the solar azimuth angle and the solar altitude angle.

[0013] Optionally, acquiring the solar azimuth angle and the solar altitude angle according to the target three-dimensional rectangular coordinate system and the geographical location information includes:

[0014] Calculating the true solar time based on the geographical location information, obtaining the solar hour angle using the true solar time, and obtaining the solar altitude angle according to the solar hour angle;

[0015] The solar azimuth is obtained according to a preset solar azimuth algorithm and by using a preset solar declination and the geographical location information.

[0016] Optionally, the determining a projection point of the obstruction on any virtual photovoltaic assembly by using the sunlight direction vector and the type of the obstruction includes:

[0017] If the type of the obstruction is the first target type, traverse all vertices of the obstruction, and determine the projection point of the obstruction of the first target type on the arbitrary virtual photovoltaic component according to all the vertices and the sunlight direction vector;

[0018] If the type of the obstruction is a second target type, a projection point of the obstruction of the second target type on the arbitrary virtual photovoltaic assembly is determined based on the shape of the obstruction of the second target type and a corresponding target calculation method.

[0019] Optionally, the determining the radiation loss coefficient corresponding to the virtual photovoltaic component by using the geographical location information, the inclination angle and the azimuth angle includes:

[0020] Obtaining the annual comprehensive irradiance of different preset photovoltaic modules with different azimuths and inclinations in different latitudes;

[0021] The target relationship between the azimuth angle, the inclination angle and the annual comprehensive irradiation at the same latitude is determined according to the annual comprehensive irradiation of the different preset photovoltaic components, and the irradiation loss coefficient corresponding to the virtual photovoltaic component is determined based on the target relationship.

[0022] Optionally, determining the annual comprehensive irradiation of the virtual photovoltaic assembly according to the total irradiation, the irradiation loss coefficient and the shadow area includes:

[0023] Acquire the radiation loss rate of the virtual photovoltaic assembly according to the radiation loss coefficient;

[0024] Obtain different shadow areas cast by the shielding object on the arbitrary virtual photovoltaic assembly in all preset time periods of a year;

[0025] The annual comprehensive irradiation of the arbitrary virtual photovoltaic component is determined according to the different shadow areas and the irradiation loss rate on the arbitrary virtual photovoltaic component in a year.

[0026] Optionally, determining a projection point of the obstruction on any virtual photovoltaic assembly includes:

[0027] Obtaining a plane equation of a target plane where the virtual photovoltaic assembly is located, and determining a positional relationship between any vertex of the obstruction and the target plane based on the plane equation;

[0028] The projection point of the shielding object on the arbitrary virtual photovoltaic assembly is determined according to the position relationship and the sunlight direction vector.

[0029] In a second aspect, the present application provides a device for determining the irradiance of a photovoltaic power station component, comprising:

[0030] A direction vector calculation module, used to obtain geographical location information of a target area, and calculate a sunlight direction vector corresponding to the target area throughout the year based on the geographical location information;

[0031] A shadow area determination module, used to determine the obstructions in the installation area of ​​the virtual photovoltaic components in the preset photovoltaic power station model according to the preset photovoltaic power station model in the target area, determine the projection point of the obstruction on any virtual photovoltaic component by using the sunlight direction vector and the type of the obstruction, and determine the shadow area cast by the obstruction on the any virtual photovoltaic component based on the projection point and the target shadow calculation method;

[0032] A loss coefficient determination module, used to determine the inclination angle between the virtual photovoltaic assembly and the ground and the azimuth angle between the virtual photovoltaic assembly and the sunlight direction vector, and determine the irradiation loss coefficient corresponding to the virtual photovoltaic assembly by using the geographical location information, the inclination angle and the azimuth angle;

[0033] The irradiation determination module is used to obtain the total irradiation of the horizontal plane per unit time from a preset meteorological data platform, and determine the annual comprehensive irradiation of the virtual photovoltaic component based on the total irradiation, the irradiation loss coefficient and the shadow area, so as to determine the installation position of the target photovoltaic component based on the annual comprehensive irradiation.

[0034] In a third aspect, the present application provides an electronic device, including:

[0035] Memory, used to store computer programs;

[0036] A processor is used to execute the computer program to implement the aforementioned method for determining the irradiation amount of a photovoltaic module.

[0037] In a fourth aspect, the present application provides a computer-readable storage medium for storing a computer program, wherein the computer program, when executed by a processor, implements the aforementioned method for determining the irradiance of a photovoltaic module.

[0038] In the present application, the geographic location information of the target area is first obtained, and the sunlight direction vector corresponding to the target area throughout the year is calculated based on the geographic location information. Then, according to the preset photovoltaic power station model in the target area, the obstructions in the installation area of ​​the virtual photovoltaic component in the preset photovoltaic power station model are determined, and the projection point of the obstruction on any virtual photovoltaic component is determined by using the sunlight direction vector and the type of the obstruction. The shadow area cast by the obstruction on the arbitrary virtual photovoltaic component is determined based on the projection point and the target shadow calculation method. Then, the inclination angle between the virtual photovoltaic component and the ground and the azimuth angle between the virtual photovoltaic component and the sunlight direction vector are determined, and the irradiation loss coefficient corresponding to the virtual photovoltaic component is determined using the geographic location information, the inclination angle and the azimuth angle. Finally, the total irradiation of the horizontal plane per unit time is obtained from the preset meteorological data platform, and the annual comprehensive irradiation of the virtual photovoltaic component is determined according to the total irradiation, the irradiation loss coefficient and the shadow area, so as to determine the installation position of the target photovoltaic component according to the annual comprehensive irradiation. It can be seen that the present application greatly improves the accuracy of the obtained irradiation by comprehensively considering the influence of azimuth and inclination on irradiation loss; by obtaining the shadow area cast by the obstruction on the virtual photovoltaic module, and using the obtained irradiation loss coefficient and shadow area to determine the annual comprehensive irradiation of the virtual photovoltaic module, the problem of unreasonable photovoltaic module installation area caused by only performing shadow area analysis in the short term is avoided. BRIEF DESCRIPTION OF THE DRAWINGS

[0039] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are only embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on the provided drawings without paying creative work.

[0040] Figure 1 A flow chart of a method for determining irradiation of a photovoltaic module disclosed in the present application;

[0041] Figure 2 A schematic diagram of a method for determining the irradiation amount of a photovoltaic module disclosed in the present application;

[0042] Figure 3 A flow chart of a method for calculating radiation attenuation rate disclosed in this application;

[0043] Figure 4 A photovoltaic module irradiation distribution color marking diagram disclosed in the present application;

[0044] Figure 5 A photovoltaic module irradiation distribution color marking diagram disclosed in the present application;

[0045] Figure 6 A flow chart for calculating the irradiance distribution of a photovoltaic module disclosed in this application;

[0046] Figure 7 A flowchart of a specific shadow area determination method disclosed in this application;

[0047] Figure 8 This is a flow chart of a shadow calculation method for an obstruction disclosed in this application;

[0048] Fig. 9 A schematic diagram of site selection for a photovoltaic power station disclosed in this application;

[0049] Fig.10 A schematic diagram of a shadow area cast by an obstruction disclosed in this application;

[0050] Fig.11 A schematic diagram of a shadow area cast by an obstruction disclosed in this application;

[0051] Fig.12 This is a schematic diagram of the structure of a photovoltaic module irradiation determination device disclosed in this application;

[0052] Fig.13 This is a structural diagram of an electronic device disclosed in this application. DETAILED DESCRIPTION

[0053] The following will be combined with the drawings in the embodiments of the present invention to clearly and completely describe the technical solutions in the embodiments of the present invention. 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 ordinary technicians in this field without creative work are within the scope of protection of the present invention.

[0054] At present, the method to solve the impact of shadows on the lighting of photovoltaic modules can only analyze the shadow situation in the short term, and there is an inaccurate analysis problem. To this end, this application provides a method for determining the irradiation of photovoltaic modules, which obtains the sunlight direction vector throughout the year and uses the sunlight direction vector to calculate the shadow area on the photovoltaic module throughout the year, thereby solving the problem of unreasonable photovoltaic module layout caused by incomplete analysis of the shadow area.

[0055] See also Figure 1 As shown, an embodiment of the present invention discloses a method for determining the irradiation amount of a photovoltaic module, comprising:

[0056] Step S11, obtaining geographical location information of a target area, and calculating a sunlight direction vector corresponding to the target area throughout the year based on the geographical location information.

[0057] In this embodiment, the overall process of obtaining the annual comprehensive irradiation of photovoltaic modules is as follows: Figure 2 As shown, first obtain the location information of the photovoltaic components and the obstructions, then calculate the solar direction vector, and obtain the comprehensive irradiation of the photovoltaic components throughout the year based on the solar direction vector and the shadow area. In this embodiment, a 3D modeling tool can be used to model the photovoltaic power station, and then obtain the specific location of the photovoltaic component installation area in the photovoltaic power station, the arrangement of the photovoltaic components, the inclination and azimuth, and the specific location and height information of the obstructions around the power station, including the roof inclination and azimuth of the roof power station. Based on this basic information, calculate the direction vector of the sunlight, and then establish a projection model of each coordinate point under the sunlight, calculate the shadow area of ​​all surrounding obstructions on the installation area and the photovoltaic components, and perform shadow simulation; then calculate the annual cumulative irradiation distribution on the installation area and the photovoltaic components based on the hourly irradiance throughout the year, and the user can optimize the component layout based on the irradiation distribution on the photovoltaic components; wherein, the process of calculating the sunlight direction vector corresponding to the target area throughout the year based on the geographic location information specifically includes: constructing a target three-dimensional rectangular coordinate system, and obtaining the solar azimuth and solar altitude angle based on the target three-dimensional rectangular coordinate system and the geographic location information; wherein The solar azimuth is the angle between the projection of the sun's rays on the horizontal plane of the target area and the meridian of the target area, and the solar altitude is the angle between the sun's rays and the horizontal plane of the target area; according to the geographic location information, the solar azimuth and the solar altitude calculate the sunlight direction vector corresponding to the target area throughout the year; wherein, the process of obtaining the solar azimuth and the solar altitude according to the target three-dimensional rectangular coordinate system and the geographic location information specifically includes: calculating the true solar time based on the geographic location information, obtaining the solar hour angle using the true solar time, and obtaining the solar altitude angle according to the solar hour angle; obtaining the solar azimuth according to the preset solar azimuth algorithm, and using the solar declination and the geographic location information. Specifically, in order to accurately calculate the sunlight direction vector, a three-dimensional rectangular coordinate system is first constructed. The coordinate system takes the observation point as the origin, wherein the x-axis points to the due east, the y-axis points to the due north, and the z-axis points vertically upward. It should be noted that the solar azimuth β refers to the angle between the projection of the sun's rays on the horizontal plane and the local meridian (due south), and its value range is between 0° and 360°. The solar altitude angle h refers to the angle between the sun's rays and the horizon, and its value range is 0° to 90°. Based on the above coordinate system, assuming that the solar altitude is According to the trigonometric function relationship, x= *sinβ / tanh,y= *cosβ / tanh, thus, the direction vector of sunlight can be expressed as (cosh*sinβ, cosh*cosβ, sinh). The calculation formula of the solar altitude angle is as follows:

[0058] ;

[0059] In addition, the calculation formula for the solar azimuth is:

[0060] ;

[0061] in, is the latitude, is the solar declination (unit: degree), and t is the solar hour angle (unit: degree). The calculation formula for solar declination is as follows, where n is the day of the year on which the current date falls.

[0062] ;

[0063] The formula for calculating the solar hour angle is:

[0064] ;

[0065] in It refers to the true solar time, and the calculation of the true solar time is more complicated. Its calculation formula is:

[0066] ;

[0067] in, It refers to the mean solar time (daily time), which is converted into minutes for unified calculation. λ is the local longitude, is the standard longitude, such as China uses the East 8 standard longitude of 120°. ∆t represents the time difference, and the time difference calculation formula is as follows:

[0068] ;

[0069] in, Refers to the sun angle, in radians; The calculation formula is as follows:

[0070] ;

[0071] in, It is the year correction value to ensure that the solar time difference can be calculated more accurately in different years. The calculation formula is as follows, where year represents the current year.

[0072] ;

[0073] Through a complete and precise calculation process, the direction vector of sunlight throughout the year can be accurately obtained, providing key data support for subsequent shadow calculations and related technical applications.

[0074] Step S12: determine the obstructions within the installation area of ​​the virtual photovoltaic components in the preset photovoltaic power station model according to the preset photovoltaic power station model in the target area, determine the projection point of the obstruction on any virtual photovoltaic component using the sunlight direction vector and the type of the obstruction, and determine the shadow area cast by the obstruction on the arbitrary virtual photovoltaic component based on the projection point and the target shadow calculation method.

[0075] In this embodiment, the process of determining the projection point of the obstruction on the virtual photovoltaic component by using the sunlight direction vector and the type of the obstruction specifically includes: if the type of the obstruction is the first target type, traversing all the vertices of the obstruction, and determining the projection point of the obstruction of the first target type on any virtual photovoltaic component based on all the vertices and the sunlight direction vector; if the type of the obstruction is the second target type, determining the projection point of the obstruction of the second target type on any virtual photovoltaic component based on the shape of the obstruction of the second target type and the corresponding target calculation method; after calculating the shadow points of all the vertices of the obstacle on the target plane, then calculating the polygon enclosed by the shadow points, and calculating the intersection of the polygon and the polygon enclosed by the target installation area to obtain the final shadow area.

[0076] Step S13, determining the inclination angle between the virtual photovoltaic component and the ground and the azimuth angle between the virtual photovoltaic component and the sunlight direction vector, and determining the radiation loss coefficient corresponding to the virtual photovoltaic component using the geographic location information, the inclination angle and the azimuth angle.

[0077] In this embodiment, the process of determining the radiation loss coefficient of the virtual photovoltaic module using geographic location information, inclination and azimuth specifically includes: obtaining the annual comprehensive radiation of different preset photovoltaic modules with different azimuths and inclinations in different latitudes; determining the target relationship between the azimuth, inclination and the annual comprehensive radiation at the same latitude based on the annual comprehensive radiation of different preset photovoltaic modules, and determining the radiation loss coefficient corresponding to the virtual photovoltaic module based on the target relationship. It should be noted that for rooftop photovoltaic power stations, the existence of the roof azimuth and inclination will affect the solar radiation received by the roof, and this influence may not be a simple linear relationship. By constructing a parabola-like model, this complex change pattern can be captured more accurately. In the process of calculating the roof radiation loss rate, key information such as the specific latitude of the power station location, the azimuth and inclination of the lighting surface are involved. By collecting the annual cumulative radiation data of the lighting surfaces with different inclinations and azimuths at different latitudes, based on the analysis and fitting of a large amount of actual data, the radiation loss under different characteristics is reflected, and a nonlinear relationship between the radiation loss and the inclination and azimuth of the lighting surface at different latitudes is obtained, that is, the above-mentioned target relationship. Based on the above-mentioned nonlinear relationship, a mathematical model that can accurately describe the complex relationship between the radiation loss rate and the azimuth and inclination is established; assuming is the latitude of the location of the photovoltaic power station, and The definition is as follows: a sample is taken every 5 latitudes, that is, the sampling latitude points are 0°, 5°, 10°…, when the latitude of the power station is is 8°, then It is 5°. That is, 10°. By collecting radiation data on multiple planes with different inclinations and azimuths at each sampling latitude point, multiple parabola coefficient data can be calculated. The main process of calculating the solar radiation attenuation rate is as follows: Figure 3 As shown, the irradiation data on the lighting surfaces with different inclinations and azimuths at different latitudes are collected, and the relationship between the azimuth, inclination and irradiation at the same latitude is analyzed to obtain three parabola coefficients. Based on the parabola coefficients, multiple irradiation values ​​under different azimuths and fixed inclinations can be calculated. Based on this value, a parabola with a fixed inclination and different azimuths can be obtained. Substituting the high and low latitudes, two such parabolas can be obtained. Substituting the azimuth into these two parabolas, the specific irradiation values ​​at high and low latitudes can be obtained, and finally the relationship between the irradiation on the plane and the latitude, inclination and azimuth can be obtained. It should be noted that in The data collected at latitude can be used to obtain the relationship between the plane inclination angle θ and the radiation amount, which can be expressed as a quadratic function. The coefficients of the quadratic function are expressed as (a1, b1, c1). Based on this set of coefficients, a point , where point The calculation formula is as follows,

[0078] ;

[0079] exist By collecting multiple sets of data at latitude, multiple points can be obtained. A parabola can be determined through these points, and a set of coefficients (d1, e1, f1) of the parabola can be calculated. The quadratic function relationship between the irradiance and the azimuth angle β can be established through the parabola coefficients. The functional relationship is shown below;

[0080] ;

[0081] Similarly, in The data collected in the latitude scenario can obtain the coefficients (a2, b2, c2) of the quadratic function between the plane inclination angle θ and the irradiance. Based on this set of coefficients, a point , the calculation formula is as follows,

[0082] ;

[0083] exist By collecting multiple sets of data at latitude, multiple points can be obtained. Through these points, a parabola can be determined and a set of coefficients (d2, e2, f2) of the parabola can be calculated. The quadratic function relationship between the irradiance and the azimuth angle β can be established through the parabola coefficients as shown below:

[0084] ;

[0085] Based on the above calculations, by analyzing the relationship between the plane inclination and the radiation at different latitudes, and establishing the quadratic function relationship between the radiation and the azimuth, we finally get the radiation loss coefficient k calculated by the latitude, the plane inclination and the azimuth. The calculation formula is as follows:

[0086] ;

[0087] in, is the latitude of the location of the photovoltaic power station, and It is the sampling points of adjacent low and high latitudes determined according to the latitude of the power station.

[0088] By analyzing the data sampled at these two latitudes, a complex relationship between the radiation loss and the plane inclination and azimuth is established. The loss coefficient can accurately reflect the specific radiation loss faced by photovoltaic power stations under various latitudes, different plane inclinations and different azimuths, providing data support for the design of photovoltaic power stations, so that the design process can more scientifically and reasonably consider the impact of different factors on the radiation, thereby achieving a more optimized power station layout and equipment configuration. After actual verification, the radiation loss calculated by the coefficient is compared with the results in the professional software PVsyst, and the accuracy rate can reach 95%, which fully proves the reliability and accuracy of the calculation method. This embodiment uses an innovative method for calculating the solar radiation attenuation rate on planes with different inclinations and azimuths. For rooftop photovoltaic power stations, due to the existence of roof azimuth and inclination, it will affect the solar radiation received by the roof. This impact may not be a simple linear relationship. By constructing a parabola-like model, this complex change law can be captured more accurately.

[0089] Step S14, obtaining the total irradiation of the horizontal plane per unit time from a preset meteorological data platform, and determining the annual comprehensive irradiation of the virtual photovoltaic component according to the total irradiation, the irradiation loss coefficient and the shadow area, so as to determine the installation position of the target photovoltaic component according to the annual comprehensive irradiation.

[0090] In this embodiment, the total irradiation of the horizontal plane per unit time is obtained, and the process of determining the annual comprehensive irradiation of the virtual photovoltaic component according to the total irradiation, the irradiation loss coefficient and the shadow area specifically includes: obtaining the irradiation loss rate of the virtual photovoltaic component according to the irradiation loss coefficient; obtaining different shadow areas projected by the obstruction on any virtual photovoltaic component in all preset time periods in a year; determining the annual comprehensive irradiation of any virtual photovoltaic component according to the different shadow areas and irradiation loss rate on any preset photovoltaic component in a year, Figure 4 and Figure 5 This is a schematic diagram of the irradiation distribution on the virtual photovoltaic module. Specifically, the process of determining the comprehensive irradiation is as follows: Figure 6 As shown in the figure, first, we obtain the total hourly horizontal radiation of the world in the past ten years from the public meteorological data platform, and calculate the average value to get the hourly horizontal radiation of the world in one year, which directly determines the solar radiation energy that the photovoltaic modules on the horizontal surface can receive, in units of , then divide the installation area of ​​PV modules of different shapes into evenly distributed grids, and assign the initial value of irradiation to the center of each grid as 0. According to the above shadow calculation method, after obtaining the shadow area of ​​the obstruction around the power station on the target plane, if a grid center is blocked by the shadow, calculate the irradiation value of the grid center after being blocked in the current hour. If it is not blocked, directly take the horizontal plane irradiation value. If the current plane has an inclination and azimuth, multiply it by the irradiation loss coefficient obtained above, so as to obtain the annual comprehensive irradiation distribution of all grid centers; after obtaining the annual comprehensive irradiation distribution of all grid centers, calculate the irradiation loss rate of the plane where the current PV module is located according to the calculation of the attenuation rate of solar irradiation on planes with different inclination and azimuth angles, and multiply the hourly initial irradiation value of the PV modules on different planes by the irradiation loss rate. Then calculate the shadow area of ​​the obstruction on the PV module for all hours of the year, and multiply the blocked PV module by a certain attenuation coefficient to obtain the annual comprehensive irradiation of all PV modules; the above public meteorological data platform can be selected according to actual application needs, and is not specifically limited here. In this embodiment, the annual comprehensive irradiation of the horizontal plane where the photovoltaic components are located without shadow is calculated as the maximum irradiation, and the irradiation value of the center point of the grid in the installation area is compared with the maximum irradiation to calculate the irradiation percentage of the grid center, and the annual comprehensive irradiation distribution of the installation area is obtained; by comparing the irradiation on all photovoltaic components with the maximum irradiation, the irradiation percentage of all photovoltaic components is calculated to obtain the annual comprehensive irradiation distribution on the photovoltaic components, thereby improving the accuracy of the irradiation distribution calculation of the photovoltaic components.

[0091] It should be noted that the shadow shielding calculation and shadow simulation methods included in the method for determining the irradiation amount of photovoltaic modules provided in the embodiment of the present invention have many other different application scenarios. For example, in residential building design, shadow shielding between building spacing leads to lighting problems, and shadow shielding of windows, balconies and other parts needs to be considered. Reasonable shadow shielding can lower indoor temperature in summer and reduce air conditioning energy consumption, but if the shielding is excessive, it may lead to insufficient indoor lighting and affect living comfort. Through the shadow calculation and shadow simulation in the present invention, the shadow conditions in different seasons and times can be predicted in the design stage, and the design of windows, balconies and shading facilities can be optimized; in animal husbandry, awnings can be reasonably set up in open-air farms to provide livestock with appropriate shade areas, reduce the impact of heat stress on livestock health and growth, and improve breeding efficiency. Through the shadow calculation and shadow simulation in the present invention, when designing the breeding area, the shadow changes in different seasons and times can be simulated, and the breeding area can be reasonably planned. Provide the best lighting environment; in the field of agricultural production, the shadow shielding in the greenhouse will affect the growth and development of crops, but excessive light can easily burn crops. By calculating the shadow shielding at different times and the irradiation distribution calculation in different areas, the degree and angle of the shade net can be accurately controlled according to the light requirements of different crops at different growth stages to form a specific shadow area. Through the shadow and irradiation distribution calculation in the present invention, the structural design of the greenhouse and the crop layout can be optimized to ensure that the crops receive uniform light; for example, according to the position of the sun and the structure of the greenhouse, the irradiation distribution in different areas is calculated, and the crop planting position is adjusted to avoid the shadow area from affecting the growth of crops. At the same time, the irradiation distribution calculation can also be used to design and control the greenhouse shading system, provide appropriate shading for crops when needed, and prevent excessive exposure; in environmental pollution monitoring and control, ultraviolet rays and other bands in solar radiation can trigger photochemical reactions in the atmosphere and produce pollutants such as ozone. Through the shadow and irradiation distribution calculation in the present invention, the photochemical reaction rate and pollutant generation in different regions and at different times can be predicted, providing an important reference for atmospheric pollution monitoring and early warning. This will help formulate appropriate pollution control strategies and reduce the occurrence of air pollution events such as photochemical smog.

[0092] It can be seen that the embodiment of the present application takes into account the actual angles and positions of the roof and photovoltaic modules according to the detailed location information of the obstructions around the photovoltaic power station, the longitude and latitude data of the power station, and the local climate information, so as to more accurately capture the complex influence of the azimuth and inclination of the roof and the angle changes of the photovoltaic modules on the solar radiation; by comprehensively calculating the shadow changes at different times throughout the year, the irradiation distribution conditions in the area where the photovoltaic power station is located and on each photovoltaic module are determined at the same time, and finally, the layout of the photovoltaic modules is optimized using the calculated shadow and irradiation distribution results; by analyzing the irradiation conditions and shadow effects at different positions in the photovoltaic power station, the position of the photovoltaic modules is adjusted to maximize the power generation efficiency of the photovoltaic power station, reduce the losses caused by shadow occlusion, and achieve optimized design and efficient operation of the photovoltaic power station.

[0093] Based on the foregoing embodiments, this application describes the specific process of determining the amount of radiation received by a photovoltaic module. Next, this application will elaborate on the process of determining the shadow area cast by the obstruction on the virtual photovoltaic module using the corresponding calculation method based on the type of obstruction.

[0094] See also Figure 7 As shown, the embodiment of the present invention discloses a process for determining a shadow area, including:

[0095] Step S21, determine the type of the obstruction. If the type of the obstruction is the first target type, traverse all vertices of the obstruction, and determine the projection point of the obstruction of the first target type on any virtual photovoltaic component based on all the vertices and the sunlight direction vector.

[0096] The shadow calculation method in this embodiment involves an innovative complex obstacle shadow algorithm, which can handle the shadow problems caused by polyhedral obstacles such as buildings and irregular obstacles such as trees under real lighting conditions. The main process is as follows: Figure 8 As shown, firstly, according to the 3D model, that is, the preset photovoltaic power station model, the following is accurately obtained: Fig. 9 The location information of the photovoltaic module installation area and the surrounding obstructions is shown, and the direction vector of the sun's rays is calculated. Then, the projection points of the vertices of each obstruction on the target plane are calculated. Then, the shadow positions of all obstructions are obtained according to the intersection of the shadow area surrounded by the projection points and the installation area. Fig.10 , Fig.11The shadow of the obstruction at different times; due to the complex shapes of the surrounding obstructions, the obstructions are divided into polyhedrons such as buildings, chimneys, and irregular obstacles such as trees, and the projection points are calculated separately; among them, the specific method for calculating the shadow points of polyhedrons such as buildings, that is, the first target type of obstruction is: the photovoltaic module installation area is set as a target plane in the three-dimensional rectangular coordinate system of space. For polyhedron obstructions such as buildings, all vertices of the object are first traversed; based on the obtained solar direction vector, the intersection of the straight line where the solar direction vector passes through a vertex and the plane is calculated, so as to determine the projection points of all vertices on the target plane. By directly calculating the projection points. Use 3D modeling tools to obtain the spatial coordinate information of each vertex, combined with the accurately determined solar ray direction vector at a specific time, through rigorous geometric calculations, the intersection of the straight line where the solar ray direction vector passes through each vertex and the target plane is obtained. These intersections constitute the projection points of the building on the target plane, and then its shadow area can be quickly determined.

[0097] Step S22: If the type of the obstruction is a second target type, determine the projection point of the obstruction of the second target type on the arbitrary virtual photovoltaic component based on the shape of the obstruction of the second target type and the corresponding target calculation method, and determine the corresponding shadow area according to the projection point.

[0098] In this embodiment, the shadow point calculation method for irregular obstacles such as trees, that is, the second target type of occluders is as follows: the tree crown is abstracted into two shapes: a sphere (including an ellipsoid) and a cone, and the trunk is abstracted into a cylinder. The spherical crown only needs to calculate the elliptical shadow area surrounded by the two tangent points of the sunlight at the left and right boundaries of the sphere or ellipse and the projection points of the upper and lower vertices on the target plane. The cone crown only needs to calculate the triangular shadow area surrounded by the tangent points of the bottom of the cone and the sunlight and the projection points of the vertices on the target plane. The following specifically describes the calculation method of the two tangent points of the sunlight at the left and right boundaries of the sphere or ellipse and the projection points of the upper and lower vertices on the target plane. The calculation method of the cone crown and the trunk is similar: the direction vector of the sunlight line (m, n, p) is known. According to the principle of perpendicular vectors, the direction vector (-n, m, 0) of the straight line passing through the center of the sphere and perpendicular to the sunlight can be obtained. The equation of the straight line can be obtained through the direction vector. It is known that the straight line passes through the center of the sphere. Assume that the center of the sphere is ( , , ), the radii of the ellipsoid on the x-axis, y-axis, and z-axis are , , , then the equation of the line is as follows, where a, b, c are the components of the direction vector of the line, and t is a scalar whose value depends on each point on the line.

[0099] ;

[0100] The equation of the ellipsoid in space is as follows,

[0101] ;

[0102] Then we can calculate the two values ​​of t, and the calculation formula is as follows:

[0103] ;

[0104] Substitute the t value into the above linear equation calculation formula to obtain the two intersection points of the line and the sphere, which are the two tangent points between the sunlight and the tree crown. The projection points of the two tangent points on the target plane can be calculated in combination with the direction vector of the sunlight, as well as the projection points of the upper and lower vertices of the tree crown on the target plane. The shadow calculation method of the tree trunk is similar, and the shadow area of ​​the tree on the target plane can be obtained.

[0105] After calculating the shadow points of all vertices of the obstacle on the target plane, the polygon enclosed by the shadow points is calculated, and the intersection of the polygon and the polygon enclosed by the target installation area is calculated to obtain the final shadow area.

[0106] It should be noted that in the process of calculating the projection point, it is necessary to pay attention to a special case, that is, when the vertex is below the target plane, this vertex will not generate a projection on the target plane. If the intersection of the straight line passing through the vertex and the plane is forcibly calculated, an incorrect result will result, so this situation must be excluded; accordingly, the process of determining the projection point of the obstruction on the virtual photovoltaic component specifically includes: obtaining the plane equation of the target plane where the virtual photovoltaic component is located, and judging the positional relationship between any vertex of the obstruction and the target plane based on the plane equation; determining the projection point of the obstruction on any virtual photovoltaic component based on the positional relationship and the direction vector of the sunlight; specifically, according to the basic properties of the plane equation, in three-dimensional space, the plane equation is generally expressed as Ax+By+Cz+D=0, where (x, y, z) are the coordinates of any point on the plane, A, B, C are the coordinate components of the normal vector of the plane (normal vector = (A, B, C)), and D is a constant. For a given point ( , , ), if A +B +C +D=0, indicating that the point is on the plane. From a further geometric analysis, if A +B +C +D>0, because the normal vector points to one side of the plane, when the point is substituted into the plane equation and a positive value is obtained, it means that the point is on the side pointed by the normal vector. +B +C +D<0, the point is on the opposite side of the direction indicated by the normal vector. In particular, C is the component of the normal vector in the z-axis direction. From a geometric point of view, when C>0, the normal vector has a component in the positive direction of the z-axis. If you imagine the plane as an object with a "positive and negative" side, then when observing along the positive direction of the z-axis, the normal vector points to the top of the plane (here the positive direction of the z-axis is defined as the top). Conversely, when C<0, it indicates that the normal vector points to the bottom of the plane. By comprehensively considering A +B +C The value of +D and the value of C can accurately determine the relative position relationship between the point and the plane, thereby avoiding calculating the wrong projection point. Shadows are calculated by innovatively using the method of abstract geometric shapes. For example, the crown of a tree is abstracted into a sphere (or ellipsoid) and a cone based on its morphological characteristics, and the trunk and chimney are abstracted into a cylinder. Other irregularly shaped objects can also refer to the corresponding abstract shapes for shadow calculation, which greatly expands the scope of application of the shadow calculation method.

[0107] It can be seen that the embodiment of the present application adopts different types of shadow area calculation methods according to the different shapes of obstructions, thereby improving the accuracy of shadow area calculation; by comparing the positional relationship between the vertex of the obstruction and the target plane, the problem of incorrect shadow area calculation when the obstruction is located under the photovoltaic module is avoided, thereby improving the reliability of the calculation process.

[0108] See also Fig.12 As shown, the embodiment of the present application discloses a photovoltaic module irradiation determination device, comprising:

[0109] A direction vector calculation module 11 is used to obtain geographical location information of a target area, and calculate a sunlight direction vector corresponding to the target area throughout the year based on the geographical location information;

[0110] A shadow area determination module 12 is used to determine the obstructions in the installation area of ​​the virtual photovoltaic components in the preset photovoltaic power station model according to the preset photovoltaic power station model in the target area, determine the projection point of the obstruction on any virtual photovoltaic component by using the sunlight direction vector and the type of the obstruction, and determine the shadow area cast by the obstruction on the any virtual photovoltaic component based on the projection point and the target shadow calculation method;

[0111] The loss coefficient determination module 13 is used to determine the inclination angle between the virtual photovoltaic component and the ground and the azimuth angle between the virtual photovoltaic component and the sunlight direction vector, and determine the irradiation loss coefficient corresponding to the virtual photovoltaic component by using the geographical location information, the inclination angle and the azimuth angle;

[0112] The irradiation determination module 14 is used to obtain the total irradiation of the horizontal plane per unit time from a preset meteorological data platform, and determine the annual comprehensive irradiation of the virtual photovoltaic component based on the total irradiation, the irradiation loss coefficient and the shadow area, so as to determine the installation position of the target photovoltaic component based on the annual comprehensive irradiation.

[0113] It can be seen that the present application greatly improves the accuracy of the obtained irradiation by comprehensively considering the influence of azimuth and inclination on irradiation loss; by obtaining the shadow area cast by the obstruction on the virtual photovoltaic module, and using the obtained irradiation loss coefficient and shadow area to determine the annual comprehensive irradiation of the virtual photovoltaic module, the problem of unreasonable photovoltaic module installation area caused by only performing shadow area analysis in the short term is avoided.

[0114] In some specific embodiments, the direction vector calculation module 11 specifically includes:

[0115] A coordinate system construction submodule is used to construct a target three-dimensional rectangular coordinate system, and obtain a solar azimuth angle and a solar altitude angle according to the target three-dimensional rectangular coordinate system and the geographical location information; wherein the solar azimuth angle is the angle between the projection of the sun's rays on the horizontal plane of the target area and the meridian of the target area, and the solar altitude angle is the angle between the sun's rays and the horizontal plane of the target area;

[0116] A direction vector calculation unit is used to calculate the sunlight direction vector corresponding to the target area throughout the year according to the geographical location information, the solar azimuth angle and the solar altitude angle.

[0117] In some specific embodiments, the coordinate system construction submodule specifically includes:

[0118] A solar altitude angle obtaining unit, configured to calculate the true solar time based on the geographical location information, obtain the solar hour angle using the true solar time, and obtain the solar altitude angle according to the solar hour angle;

[0119] The solar azimuth angle acquisition unit is used to acquire the solar azimuth angle according to a preset solar azimuth angle algorithm and by using a preset solar declination and the geographical location information.

[0120] In some specific embodiments, the shadow area determination module 12 specifically includes:

[0121] A first projection point determination unit, configured to, if the type of the obstruction is a first target type, traverse all vertices of the obstruction, and determine a projection point of the obstruction of the first target type on the arbitrary virtual photovoltaic assembly according to all the vertices and the sunlight direction vector;

[0122] The second projection point determination unit is used to determine the projection point of the obstruction of the second target type on the arbitrary virtual photovoltaic component based on the shape of the obstruction of the second target type and the corresponding target calculation method if the type of the obstruction is a second target type.

[0123] In some specific embodiments, the loss coefficient determination module 13 specifically includes:

[0124] An irradiation acquisition unit, used for acquiring the annual comprehensive irradiation of different preset photovoltaic modules with different azimuths and inclinations in different latitudes;

[0125] A loss coefficient determination unit is used to determine the target relationship between the azimuth angle, the inclination angle and the annual comprehensive irradiation at the same latitude according to the annual comprehensive irradiation of the different preset photovoltaic components, and determine the irradiation loss coefficient corresponding to the virtual photovoltaic component based on the target relationship.

[0126] In some specific embodiments, the radiation amount determination module 14 specifically includes:

[0127] An irradiation loss rate acquisition unit, used to acquire the irradiation loss rate of the virtual photovoltaic assembly according to the irradiation loss coefficient;

[0128] A shadow area acquisition unit, used to acquire different shadow areas cast by the shielding object on the arbitrary virtual photovoltaic assembly in all preset time periods of a year;

[0129] The radiation amount acquisition unit is used to determine the annual comprehensive radiation amount of the arbitrary virtual photovoltaic component according to the different shadow areas and the radiation loss rate on the arbitrary preset photovoltaic component in a year.

[0130] In some specific embodiments, the shadow area determination module 12 specifically includes:

[0131] A position relationship determination unit, used for obtaining a plane equation of a target plane where the virtual photovoltaic assembly is located, and determining a position relationship between any vertex of the obstruction and the target plane based on the plane equation;

[0132] The third projection point determination unit is used to determine the projection point of the obstruction on the arbitrary virtual photovoltaic assembly according to the position relationship and the sunlight direction vector.

[0133] Furthermore, the present application also discloses an electronic device. Fig.13 This is a structural diagram of an electronic device 20 according to an exemplary embodiment. The content in the diagram cannot be regarded as any limitation on the scope of use of the present application.

[0134] Fig.13 A schematic diagram of the structure of an electronic device 20 provided in an embodiment of the present application. The electronic device 20 may specifically include: at least one processor 21, at least one memory 22, a power supply 23, a communication interface 24, an input / output interface 25, and a communication bus 26. The memory 22 is used to store a computer program, which is loaded and executed by the processor 21 to implement the relevant steps in the method for determining the irradiation amount of a photovoltaic module disclosed in any of the aforementioned embodiments. In addition, the electronic device 20 in this embodiment may specifically be an electronic computer.

[0135] In this embodiment, the power supply 23 is used to provide working voltage for each hardware device on the electronic device 20; the communication interface 24 can create a data transmission channel between the electronic device 20 and the external device, and the communication protocol it follows is any communication protocol that can be applied to the technical solution of the present application, and is not specifically limited here; the input and output interface 25 is used to obtain external input data or output data to the outside world, and its specific interface type can be selected according to specific application needs and is not specifically limited here.

[0136] In addition, the memory 22 as a carrier for storing resources may be a read-only memory, a random access memory, a disk or an optical disk, etc. The resources stored thereon may include an operating system 221, a computer program 222, etc., and the storage method may be temporary storage or permanent storage.

[0137] The operating system 221 is used to manage and control the hardware devices and computer program 222 on the electronic device 20, which can be Windows Server, Netware, Unix, Linux, etc. In addition to including a computer program that can be used to complete the method for determining the irradiation amount of a photovoltaic module executed by the electronic device 20 disclosed in any of the aforementioned embodiments, the computer program 222 can further include a computer program that can be used to complete other specific tasks.

[0138] Furthermore, the present application also discloses a computer-readable storage medium for storing a computer program; wherein, when the computer program is executed by a processor, the aforementioned photovoltaic module irradiation determination method is implemented. The specific steps of the method can be referred to the corresponding contents disclosed in the aforementioned embodiments, and will not be repeated here.

[0139] In this specification, each embodiment is described in a progressive manner, and each embodiment focuses on the differences from other embodiments. The same or similar parts between the embodiments can be referred to each other. For the device disclosed in the embodiment, since it corresponds to the method disclosed in the embodiment, the description is relatively simple, and the relevant parts can be referred to the method part.

[0140] Professionals may further appreciate that the units and algorithm steps of each example described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, computer software, or a combination of the two. In order to clearly illustrate the interchangeability of hardware and software, the composition and steps of each example have been generally described in the above description according to function. Whether these functions are performed in hardware or software depends on the specific application and design constraints of the technical solution. Professionals and technicians may use different methods to implement the described functions for each specific application, but such implementation should not be considered to be beyond the scope of this application.

[0141] The steps of the method or algorithm described in conjunction with the embodiments disclosed herein may be implemented directly using hardware, a software module executed by a processor, or a combination of the two. The software module may be placed in a random access memory (RAM), a memory, a read-only memory (ROM), an electrically programmable ROM, an electrically erasable programmable ROM, a register, a hard disk, a removable disk, a CD-ROM, or any other form of storage medium known in the art.

[0142] Finally, it should be noted that, in this article, relational terms such as first and second, etc. are only used to distinguish one entity or operation from another entity or operation, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Moreover, the terms "include", "comprise" or any other variants thereof are intended to cover non-exclusive inclusion, so that a process, method, article or device including a series of elements includes not only those elements, but also other elements not explicitly listed, or also includes elements inherent to such process, method, article or device. In the absence of further restrictions, the elements defined by the sentence "comprise a ..." do not exclude the presence of other identical elements in the process, method, article or device including the elements.

[0143] The technical solution provided by the present application is introduced in detail above. Specific examples are used in this article to illustrate the principles and implementation methods of the present application. The description of the above embodiments is only used to help understand the method of the present application and its core idea. At the same time, for general technicians in this field, according to the idea of ​​the present application, there will be changes in the specific implementation methods and application scope. In summary, the content of this specification should not be understood as a limitation on the present application.

Claims

1. A method for determining the irradiation amount of a photovoltaic module, characterized in that: include: Acquire geographic location information of a target area, and calculate a sunlight direction vector corresponding to the target area throughout the year based on the geographic location information; Determine the obstructions within the installation area of ​​the virtual photovoltaic components in the preset photovoltaic power station model according to the preset photovoltaic power station model in the target area, determine the projection point of the obstruction on any virtual photovoltaic component using the sunlight direction vector and the type of the obstruction, and determine the shadow area cast by the obstruction on the any virtual photovoltaic component based on the projection point and the target shadow calculation method; Determine the inclination angle between the virtual photovoltaic assembly and the ground and the azimuth angle between the virtual photovoltaic assembly and the sunlight direction vector, and determine the radiation loss coefficient corresponding to the virtual photovoltaic assembly using the geographical location information, the inclination angle and the azimuth angle; The total irradiance of the horizontal plane per unit time is obtained from a preset meteorological data platform, and the annual comprehensive irradiance of the virtual photovoltaic component is determined according to the total irradiance, the irradiance loss coefficient and the shadow area, so as to determine the installation position of the target photovoltaic component according to the annual comprehensive irradiance.

2. The method for determining the irradiation amount of a photovoltaic module according to claim 1, characterized in that: The calculating the sunlight direction vector corresponding to the target area throughout the year based on the geographical location information includes: Constructing a target three-dimensional rectangular coordinate system, and acquiring a solar azimuth angle and a solar altitude angle according to the target three-dimensional rectangular coordinate system and the geographical location information; wherein the solar azimuth angle is the angle between the projection of the sun's rays on the horizontal plane of the target area and the meridian of the target area, and the solar altitude angle is the angle between the sun's rays and the horizontal plane of the target area; The sunlight direction vector corresponding to the target area throughout the year is calculated according to the geographical location information, the solar azimuth angle and the solar altitude angle.

3. The method for determining the irradiation amount of a photovoltaic module according to claim 2, characterized in that: The step of obtaining the solar azimuth angle and the solar altitude angle according to the target three-dimensional rectangular coordinate system and the geographical location information includes: Calculating the true solar time based on the geographical location information, obtaining the solar hour angle using the true solar time, and obtaining the solar altitude angle according to the solar hour angle; The solar azimuth is obtained according to a preset solar azimuth algorithm and by using a preset solar declination and the geographical location information.

4. The method for determining the irradiation amount of a photovoltaic module according to claim 1, characterized in that: The step of determining the projection point of the obstruction on any virtual photovoltaic assembly by using the sunlight direction vector and the type of the obstruction includes: If the type of the obstruction is the first target type, traverse all vertices of the obstruction, and determine the projection point of the obstruction of the first target type on the arbitrary virtual photovoltaic component according to all the vertices and the sunlight direction vector; If the type of the obstruction is a second target type, a projection point of the obstruction of the second target type on the arbitrary virtual photovoltaic assembly is determined based on the shape of the obstruction of the second target type and a corresponding target calculation method.

5. The method for determining the irradiation amount of a photovoltaic module according to claim 1, characterized in that: The determining of the radiation loss coefficient corresponding to the virtual photovoltaic component by using the geographical location information, the inclination angle and the azimuth angle includes: Obtaining the annual comprehensive irradiance of different preset photovoltaic modules with different azimuths and inclinations in different latitudes; The target relationship between the azimuth angle, the inclination angle and the annual comprehensive irradiation at the same latitude is determined according to the annual comprehensive irradiation of the different preset photovoltaic components, and the irradiation loss coefficient corresponding to the virtual photovoltaic component is determined based on the target relationship.

6. The method for determining the irradiation amount of a photovoltaic module according to claim 1, characterized in that: The determining of the annual comprehensive irradiation of the virtual photovoltaic assembly according to the total irradiation, the irradiation loss coefficient and the shadow area includes: Acquire the radiation loss rate of the virtual photovoltaic assembly according to the radiation loss coefficient; Obtain different shadow areas cast by the shielding object on the arbitrary virtual photovoltaic assembly in all preset time periods of a year; The annual comprehensive irradiation of the arbitrary virtual photovoltaic component is determined according to the different shadow areas and the irradiation loss rate on the arbitrary virtual photovoltaic component in a year.

7. The method for determining the irradiation amount of a photovoltaic module according to any one of claims 1 to 6, characterized in that: The determining of the projection point of the obstruction on any virtual photovoltaic assembly includes: Obtaining a plane equation of a target plane where the virtual photovoltaic assembly is located, and determining a positional relationship between any vertex of the obstruction and the target plane based on the plane equation; The projection point of the shielding object on the arbitrary virtual photovoltaic assembly is determined according to the position relationship and the sunlight direction vector.

8. A device for determining the irradiation amount of a photovoltaic module, characterized in that: include: A direction vector calculation module, used to obtain geographical location information of a target area, and calculate a sunlight direction vector corresponding to the target area throughout the year based on the geographical location information; A shadow area determination module, used to determine the obstructions in the installation area of ​​the virtual photovoltaic components in the preset photovoltaic power station model according to the preset photovoltaic power station model in the target area, determine the projection point of the obstruction on any virtual photovoltaic component by using the sunlight direction vector and the type of the obstruction, and determine the shadow area cast by the obstruction on the any virtual photovoltaic component based on the projection point and the target shadow calculation method; A loss coefficient determination module, used to determine the inclination angle between the virtual photovoltaic assembly and the ground and the azimuth angle between the virtual photovoltaic assembly and the sunlight direction vector, and determine the irradiation loss coefficient corresponding to the virtual photovoltaic assembly by using the geographical location information, the inclination angle and the azimuth angle; The irradiation determination module is used to obtain the total irradiation of the horizontal plane per unit time from a preset meteorological data platform, and determine the annual comprehensive irradiation of the virtual photovoltaic component based on the total irradiation, the irradiation loss coefficient and the shadow area, so as to determine the installation position of the target photovoltaic component based on the annual comprehensive irradiation.

9. An electronic device, characterized in that: include: Memory, used to store computer programs; A processor is used to execute the computer program to implement the method for determining the irradiation amount of a photovoltaic module as described in any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that: Used to store a computer program, which, when executed by a processor, implements the method for determining the irradiation amount of a photovoltaic component as described in any one of claims 1 to 7.

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