Sunlight tracking on solar panels

Abstract

A method for designing and building a photovoltaic solar system and a collector at a predetermined location includes calculating a daily average TMY sunshine value from TMY data for a predetermined direction of the collector, calculating a daily average sunshine loss value from one or more sunshine barriers, calculating a daily average temperature derated sunshine loss value, and calculating a daily average temperature derated sunshine loss value. Calculating a daily average effective sunshine value by subtracting a sun shading loss value and a derating loss value from the TMY sunshine value, determining a minimum energy output requirement of the PV solar system, determining a minimum required PV area of the collector based on the minimum energy output requirement and the daily average effective sunshine value, and building the PV solar system at a predetermined location, wherein the collector is in a predetermined orientation. The collector has at least the minimum desired PV area.

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

[0001] This application claims the benefit of U.S. Provisional Patent Application No. 63 / 561,825, filed on March 6, 2024, and entitled “Sunlight Tracking on Solar Panels,” the entire contents of which are incorporated herein by reference. Technical Field

[0002] The embodiments described herein relate generally to solar panel installations and, more particularly, to a method of designing and building solar panels that reliably meet energy needs. Background Art

[0003] Global energy demand has reached unprecedented levels over the past few decades. The need to reduce greenhouse gases (the cause of global warming from burning fossil fuels to meet energy demand) has spurred global attention to the utilization of renewable, sustainable, and cleaner energy alternatives. Since the 1870s, increasing fossil fuel combustion as a result of the Industrial Revolution has led to a dramatic increase in atmospheric carbon dioxide (CO2) concentrations. This increase in activity has been the primary cause of global warming over the past five decades. Because natural processes cannot rapidly remove CO2 from the atmosphere, future emissions, if allowed to continue, will have impacts on the climate system for millennia.

[0004] Solar energy is the most promising form of renewable energy for curbing global energy demand and reducing greenhouse gas emissions. First, solar energy is clean, generating electricity without emitting greenhouse gases and toxic gases such as CO2 and nitrogen oxides (NOx). Second, economically speaking, solar energy has a positive impact after the initial investment, translating into reduced electricity bills and potential new jobs. Third, solar energy is relatively easy to install on commercial rooftops while generating clean electricity.

[0005] Buildings, including commercial and residential properties, account for approximately 40% of global energy consumption and play a significant role in energy markets. These buildings provide vital infrastructure for human needs, and while their countless benefits to society cannot be ignored, heating, cooling, and lighting buildings with fossil fuels have a devastating impact on the environment. The future outcomes of anthropogenic climate change driven by fossil fuels by the turn of the century present both high risk and high uncertainty. To do our part to ensure that global civilization as we know it continues to thrive, we must strongly consider implementing alternative energy sources, such as solar energy, as renewable, affordable, and sustainable energy technology alternatives to fossil fuels.

[0006] The potential for solar energy utilization depends on the amount of sunlight reaching the Earth's surface, known as solar insolation. Several factors, such as weather patterns, humidity, and haze, can influence local insolation levels. However, there is currently no simplified method for designing and building a viable and economical photovoltaic (PV) solar system that can account for insolation and the various factors that influence it to reliably build a system of sufficient size and orientation to meet power output requirements. Summary of the Invention

[0007] Briefly, one exemplary embodiment includes a method for designing and constructing a photovoltaic (PV) solar energy system at a predetermined location, wherein the PV solar energy system includes at least one collector. The method includes calculating a daily average typical meteorological year (TMY) insolation value based on TMY data for a predetermined orientation of the at least one collector of the PV solar energy system, calculating a daily average shading insolation loss value for the predetermined location due to one or more shading obstacles and the predetermined orientation of the at least one collector of the PV solar energy system, calculating a daily average temperature derating insolation loss value at the predetermined location, calculating a daily average effective insolation value for the predetermined location and predetermined orientation of the at least one collector of the PV solar energy system by subtracting the daily average shading insolation loss value and the daily average temperature derating insolation loss value from the daily average TMY insolation value, determining a minimum energy output requirement for the PV solar energy system, determining a minimum required PV area for the at least one collector of the PV solar energy system based on the minimum energy output requirement and the daily average effective insolation value, and constructing the PV solar energy system at the predetermined location, wherein the at least one collector is in the predetermined orientation. The at least one collector of the PV solar energy system has at least the minimum required PV area.

[0008] In one aspect, the TMY data includes at least the global horizontal irradiance (GHI), direct normal irradiance (DNI), and diffuse horizontal irradiance (DHI) at the latitude and longitude of the predetermined location on at least one selected day of the year and within one or more selected hours of the selected day. In another aspect, calculating the daily average TMY insolation value includes calculating the direct beam irradiance I on the at least one collector. BC , diffuse radiation I on the at least one collector DC and the reflected radiation I on the at least one collector RC Add to calculate the at least one collector I C Total radiation on the BC Depends on DNI,I DC Depends on DHI, I RC Depends on GHI.

[0009] In another aspect, the predetermined orientation of the at least one collector of the PV solar energy system is a fixed orientation, wherein the at least one collector is fixedly facing a single predetermined direction and is fixedly tilted relative to a local horizon at a predetermined collector tilt angle.

[0010] In another aspect, the predetermined orientation of the at least one collector of the PV solar energy system is a single-axis orbit, wherein the PV solar energy system moves the at least one collector on a single axis to track the position of the sun in a generally east-west trajectory.

[0011] In another aspect, the predetermined orientation of the at least one collector of the PV solar system is a dual-axis orbit, wherein the PV solar system moves the at least one collector in two axes to track the position of the sun in a generally east-west trajectory and a generally north-south trajectory.

[0012] In another aspect, calculating the daily average shading insolation loss value includes determining an azimuth and an altitude of each of the one or more shading obstacles, and determining one or more time periods by comparing the azimuth and altitude of each of the one or more shading obstacles with the path of the sun at the predetermined location within one or more selected hours on at least one selected date of the year, during which the at least one collector of the PV solar energy system is blocked by each of the one or more shading obstacles.

[0013] In another aspect, calculating the daily average temperature derating insolation loss value is based at least on a nominal operating cell temperature (NOCT) of the at least one collector and an ambient temperature of the predetermined location during one or more selected hours on at least one selected day of the year. BRIEF DESCRIPTION OF THE DRAWINGS

[0014] The following detailed description of the preferred embodiment will be better understood when read in conjunction with the accompanying drawings. For illustrative purposes, there are shown in the accompanying drawings presently preferred embodiments. However, it should be understood that the invention is not limited to the precise arrangements and instrumentalities shown.

[0015] In the attached figure:

[0016] Figure 1 is a flow chart of an example method according to an embodiment of the present invention;

[0017] Figure 2 is based on Figure 1 A schematic diagram of an example PV solar system constructed using the method; and

[0018] Figure 3 is an example comparison of a sunshade barrier and the sun path, as Figure 1 part of the method. DETAILED DESCRIPTION

[0019] Certain terminology is used in the following description for convenience only and is not limiting. The words "right," "left," "lower," and "upper" designate directions in the accompanying drawings. The words "inwardly" and "outwardly" refer to directions toward and away from, respectively, the geometric center of the device and designated parts thereof. The terminology includes the aforementioned words, their derivatives, and words of similar import. Furthermore, the words "a" and "an," as used in the claims and corresponding portions of the specification, mean "at least one."

[0020] It should also be understood that the terms "approximately," "generally," "substantially," and similar terms used herein when referring to a dimension or feature of a component indicate that the described dimension / feature is not a strict boundary or parameter and does not exclude minor variations that are functionally similar. At a minimum, such references including numerical parameters will include variations that do not change the least significant digit using mathematical and industrial principles generally recognized in the art (e.g., rounding, measurement or other systematic errors, manufacturing tolerances, etc.).

[0021] Figure 2 is a schematic diagram of an example PV solar energy system 10 that may be designed and constructed at a predetermined location according to an embodiment of the present invention. The PV solar energy system 10 is shown as being mounted on a rooftop of a facility 12, and the PV solar energy system may provide generated electricity through exposure to the sun 14. Although shown as being mounted on the rooftop of the facility 12, the PV solar energy system 10 may also be a ground-mounted system, or may be mounted on the rooftop of an adjacent building or other structure. In particular, the design and construction of the PV solar energy system 10 may take into account the typical expected daily insolation from the sun 14, the expected losses from nearby shading obstacles (such as trees 16, etc.), and the losses due to the operation of one or more collectors 18 of the PV solar energy system 10 being affected by temperature.

[0022] The PV solar system 10 can have a predetermined orientation, which generally falls into three main categories. The first is a fixed orientation, in which at least one collector 18 is fixedly facing a single predetermined direction (e.g., south, etc.) and is fixedly tilted relative to the local horizon 20 at a predetermined collector tilt angle. The orientation and tilt angle are generally selected to maximize exposure to sunlight as the sun 14 passes overhead. As explained in further detail below, methods for determining the average daily effective insolation can help select the orientation and tilt angle of the collector 18. The fixed orientation is generally the least expensive of the PV solar system installation types because no moving parts and motors are required.

[0023] The second type of orientation is single-axis orbit, in which the PV solar system 10 moves the collector 18 on a single axis to track the position of the sun 14 in a roughly east-west trajectory. This movement allows the sun 14 to face more direct sunlight as it moves across the sky, resulting in higher power generation and greater efficiency. However, this single-axis PV solar system 10 involves a higher initial cost due to the moving parts and energy required to operate the motors that move the collector 18 throughout the day. This type also incurs maintenance costs to maintain the functioning of the moving parts over its lifetime. The third type of orientation is dual-axis orbit, in which the PV solar system 10 moves the collector 18 on two axes to track the position of the sun 14 in both a roughly east-west trajectory and a roughly north-south trajectory. Because the direction of the sun 14 changes throughout the year, dual-axis systems, due to their additional degree of freedom of movement, can always face the sun 14 directly, maximizing power generation and efficiency. However, this technology is also the most expensive. It is conceivable that when designing a PV solar system 10, cost considerations should be taken into account when selecting its intended orientation.

[0024] Various types of collectors 18 are also contemplated, and some of their characteristics are exploited in the method described below for designing the overall PV solar system 10. Single crystal collectors have the highest efficiency ratings among solar cells due to their fabrication using high-grade silicon. The advantage of a single crystal structure is that the electrons within the crystal have greater roaming ability, resulting in greater electron-hole pairs and higher photovoltaic conversion, leading to higher currents and thus higher overall efficiency. This technology typically converts over 21% of sunlight into electricity, making it more efficient than multicrystalline silicon collectors. However, due to the high purity of the material, single crystal systems are also the most expensive.

[0025] Polycrystalline silicon (p-Si) collectors are cheaper than single-crystal technology. However, p-Si technology is generally less efficient (~15%), has poorer heat tolerance, requires a larger surface area to output the same electrical power as single-crystal silicon technology, and has lower silicon purity than its competitors. p-Si technology embeds multiple silicon crystal fragments in each cell, resulting in less freedom for electron movement and thus lower efficiency. However, p-Si collectors do have a comparable lifespan to single-crystal collectors.

[0026] Amorphous (a-Si) collector technology has been commercially available for over two decades, powering LED lighting. The low manufacturing cost of amorphous cells makes this collector highly cost-competitive. A drawback of a-Si technology is often its unstructured, glassy silicon structure, which provides limited order to the atomic arrangement within the cell. This creates an unstable electron (a "dangling bond") that cannot bind. After being excited by a photon, the unstable electron falls back to the valence band, where it can be harvested and converted into useful energy. This drawback contributes to the technology's low efficiency rating of approximately 9%.

[0027] Cadmium telluride (CdTe) collectors are the second most used technology after silicon and involve thin-film technology that absorbs photons and converts them into electricity. The technology uses two types of cadmium molecules (cadmium sulfide and cadmium telluride) to achieve the properties necessary for photon conversion, thereby reducing the amount of material needed for production. One potential drawback of the technology is that it is listed as one of the six most deadly toxic substances known. Currently, the most widely accepted view in the United States is that the use of cadmium telluride in residential and industrial rooftop solar installations does not pose a significant threat to the environment.

[0028] Thin-film collectors are a second-generation technology made by depositing one or more thin films onto a substrate such as glass, plastic, or metal. This technology is commercially used alongside competing technologies, including CdTe, amorphous silicon (a-Si), and thin-film silicon (TF-Si). This technology generally offers flexibility and lower comparative costs.

[0029] Concentrated photovoltaic (CPV) collectors are used by large power generators, such as Georgia Power, to efficiently convert solar radiation into electricity, but they can be scaled up for commercial applications. CPV includes an advanced optical system of highly magnified lenses and curved mirrors to convert solar energy into electricity with an efficiency of 41%. The technology requires high-performance trackers that can intelligently and automatically follow the sun throughout the day. While highly efficient, the initial capital cost, operating and manufacturing costs, and installation space requirements can be prohibitive.

[0030] Figure 1 is used to design and build Figure 2Flowchart of an example embodiment of method 100 for a PV solar energy system 10 is shown. An initial step in method 100 may be performing a physical site assessment to determine the solar radiation potential of the site, identify potential sun path obstructions that may result in shading and corresponding solar radiation loss for the solar energy system, and determine an ideal site location for the photovoltaic solar energy system. The site assessment may also determine the feasibility of ground mounted solar panels versus roof mounted panels. Building and site measurements and building roof slopes (if necessary) may be obtained from existing or future site plans and / or direct measurements. For example, building area, facility area, and roof slopes may be obtained. Suitable ground or oriented roofs that may be used for the PV solar energy system may be measured, particularly roofs that allow for maximum solar exposure.

[0031] It is also preferred to obtain the latitude and longitude coordinates of the predetermined location. For example, the coordinates can be obtained using a handheld true north compass, thus avoiding the task of correcting for discrepancies between true north and magnetic north readings. The azimuth and altitude of potential obstructions on site can also be obtained using a true north compass and a handheld magnetic protractor angle locator.

[0032] At step 102, a daily average typical meteorological year (TMY) insolation value can be calculated based on TMY data for a predetermined orientation of at least one collector of the PV solar energy system. The TMY data that can be used to determine the effective amount of insolation available on the at least one collector can provide "real-time," location-specific, hourly estimates of normal (vertical) and horizontal (relative to the Earth's surface) extraterrestrial radiation (ETRN ETR), global horizontal irradiance (GHI), direct normal irradiance (DNI), and diffuse horizontal irradiance (DHI), and can further account for important factors such as wind speed, temperature, humidity, illuminance, and precipitation that affect the amount of insolation available on the at least one receiver. For example, TMY data for a specific location can be retrieved in the National Solar Radiation Database (NSRDB) data viewer. After retrieving the necessary TMY data, the hourly, monthly, and / or yearly TMY insolation can be calculated using one or more orientations of the at least one collector of the planned PV solar energy system. For example, multiple collector azimuths and tilt angles can be tested to determine the optimal azimuth and tilt angle for maximum insolation exposure on the collector.

[0033] The following equations can be used for fixed direction collectors: I BC =I B cosθ (for all directions) C=0.095+0.04sin[360 / 365(n-100)] I DC =I B C(1+cosΣ) / 2 I RC =I B ρ(C+sinβ)(1-cosΣ) / 2 I C =I BC +I DC +I RC Among them, I BC is the direct beam radiation on the collector, I DC is the diffuse radiation scattered by atmospheric particles and moisture or reflected from clouds onto the collector, I RC is the radiation received by the collector that is reflected from the surfaces surrounding the collector, I C is the total radiation on the collector, I B is the incident clear beam radiation arriving at a point on the Earth's surface, θ is the angle of incidence as a function of the collector direction, β is the solar altitude, is the solar azimuth, is the collector azimuth, ∑ is the collector tilt angle, C is the sky diffuse factor used in the Threkeld and Jordan equation, n is the day of a given month, and ρ is the ground reflectivity coefficient (0 to 1.0).

[0034] For a single-axis orbital collector, the equations may change depending on whether the orientation is horizontal north-south (HNS) or horizontal east-west (HEW): I BC =I B cosθ I DC =I B C[1+(sinβ / cosθ)] / 2 I RC =I B ρ(C+sinβ)[1-(sinβ / cosθ)] / 2 I C =I BC +I DC +I RC And for a dual-axis track collector: cosθ=1 I BC =I B I DC =I B C(1+sinβ) / 2 IRC =I B ρ(C+sinβ)(1-sinβ) / 2 I C =I BC +I DC +I RC

[0035] The above DNI TMY data can be used instead of I B , so I BC =DNI cosθ. In addition, in order to calculate the total solar radiation I C , Factor I B C can be replaced by DHI, factor I B ρ can be replaced by GHIρ.

[0036] The daily average TMY sunshine value can be calculated by taking the sum of the total TMY sunshine values ​​(or a fraction thereof) for a year and dividing it by the corresponding number of days. For example, the table below shows the daily TMY sunshine values ​​calculated on the 21st of each month for various tilt angles of a fixed-direction collector at a specified location. By multiplying each daily TMY sunshine value by the number of days in the corresponding month and adding the results for the whole year, the total TMY sunshine value for each year can be determined from these data. In this example, at the predetermined location, for a tilt angle of 22.62°, the maximum total sunshine value is 1874 kWh / m 2 / yr. Divide the total TMY sunshine by 365, and the average daily TMY sunshine value is 5.13kWh / m 2 / day. However, other methods of determining daily averages may also be used. For example, you can use a different representative day of the month, you can use multiple days of the month, you can select fewer months, and so on.

[0037] At step 104, a daily average shading solar insolation loss value is calculated for a predetermined location due to one or more shading obstacles and a predetermined orientation of at least one collector of the PV solar system. First, potential shading obstacles, such as trees, buildings, and hills, can be identified. For each such shading obstacle, an azimuth and elevation angle can be determined, for example, in the manner described above. The following table summarizes information about tree buffer zones identified as potential shading obstacles at the example predetermined location described above.

[0038] Potential shading obstructions may be compared to the path of the sun at a predetermined location for at least one selected day of the year, during one or more selected hours on the selected day. Figure 3An example comparison of the above-described tree obstructions is shown superimposed on a sun path diagram showing the altitude and azimuth of the sun for a given month and time. From such a comparison, one or more time periods can be determined during which the collector was blocked from sunlight by one of the shading obstructions. In the example provided, it can be determined that the tree blocked the collector between 6:00 AM and 10:00 AM and 1:45 PM and 6:00 PM on January 21st. Based on the TMY insolation analysis, the hourly insolation for these time periods can be summed to determine how much of the sunlight was ultimately blocked by the shading obstructions during these time periods. This analysis can be repeated in various ways to obtain a daily average shading solar loss value for a predetermined location, such as by sampling different days of the year to estimate the annual shading solar loss divided by the number of days, although other techniques can also be used to analyze the information to obtain a daily average shading solar loss value. In the example provided, the daily average shading solar loss was found to be 1.48 kW / m 2 / sky.

[0039] In some embodiments, it may be determined that the collector may be only partially shaded by a shading obstacle during certain time periods. In this case, a corresponding percentage of the hourly TMY sunlight amount may be calculated, for example, reflecting the portion of the collector area that is shaded.

[0040] At step 106, the derated solar radiation loss value is calculated for the daily average temperature at the predetermined location. The derated factor can be used to account for the solar radiation loss caused by operating the solar cell at a temperature higher or lower than the nominal operating cell temperature (NOCT) specified by the manufacturer. NOCT is the solar radiation loss when the ambient temperature is 20°C and the solar radiation is 0.8kW / m 2 , the expected battery temperature in the module at a wind speed of 1m / s. The following equation can be used to determine the battery temperature required to calculate the collector temperature derating factor: T cell =T amb +[(NOCT-20℃) / 0.8]x S Among them, T cell is the battery temperature (°C), T amb is the ambient temperature, S is the amount of sunshine (kW / m 2 ). Then, the T cell The values ​​can be used in the following equation to derive the derating factor for a predetermined location at a specific time on a specific date: P max Decline = P max (% / ℃) Temperature coefficient x(T cell -STC battery temperature) NOCT derating = 1-Pmax reduction (%) Among them, P maxThe temperature coefficient (% / °C) and the standard test condition (STC) cell temperature may be provided in the manufacturer's PV collector performance data sheet or may be determined by independent testing of a specific collector.

[0041] The sunlight loss due to derating can then be calculated by, for example, taking the hourly sunlight for TMY and calculating the sunlight loss due to NOCT derating. As with the other data, the daily average derating sunlight loss value can be calculated by taking the full (or partial) year data from as many sample points as are deemed appropriate or accurate and dividing by the total number of days, but other methods can also be used. In the example presented in this article, the daily average NOCT derating was found to be 0.92, resulting in a daily average temperature derating sunlight loss of 0.41 kWh / m 2 / day (5.13 x 0.08).

[0042] At step 108, the daily average effective insolation value for the predetermined location and predetermined direction of at least one collector of the PV solar system may be calculated. Specifically, the daily average shading insolation loss value and the daily average temperature derating insolation loss value may be subtracted from the daily average TMY insolation value. In the example provided herein, the daily average effective insolation value for the predetermined location is 3.24 kWh / m 2 / day (5.13-1.48-0.41). It should be noted that although step 108 is shown and described as a discrete step, the subtraction of shading and derating losses can be considered and included in the previous steps, for example, the daily average TMY insolation can be multiplied by the NOCT derating, and then the shading loss insolation value can be subtracted from the resulting value to obtain the daily average effective insolation value, although other mathematical variations can also be used to effectively subtract the shading and derating losses from the TMY insolation.

[0043] At step 110, the minimum energy output requirement for the PV solar energy system may be determined. For example, the historical energy consumed by the infrastructure intended to be powered by the PV solar energy system may be averaged to estimate the minimum energy output requirement. This average may be supplemented to provide a buffer to account for expected excesses. In other examples, historical data may provide a maximum usage that may be set as the minimum energy output requirement. Other methods of analyzing historical energy data and determining the minimum energy output requirement may also be performed, including situations where the PV solar energy system may not be required to provide the entire energy supply. In some other embodiments, there may be no historical consumption data to analyze, such as where a new residence or commercial facility is being built. In these cases, the minimum energy output requirement must be estimated based on the expected installation of power consuming equipment (such as appliances, outlets, computers, servers, or similar powered equipment), expected operating hours, consumption by similarly sized facilities, neighboring consumption, and other similar factors. Although Figure 1Step 110 is shown as being performed after steps 102-108, but may also be performed before calculating the insolation data. In the example described herein, the minimum energy output requirement may be calculated to be 1,200,000 kWh / y.

[0044] At step 112, the minimum required PV area of ​​at least one collector of the PV solar energy system may be determined based on the minimum energy output requirement and the average daily effective insolation value. For example, the following equation may be used to calculate the required minimum area A: A(m 2 )=P DC / (1kWm 2 xη) P DC (kW) = Energy (kWh / yr) / (Daily average effective sunshine x 365d / yr) Among them, P DC is the required DC power provided by the solar array and η is the collector manufacturer’s efficiency rating.

[0045] Using the example described in this article, the minimum required amount of electricity that a PV solar system needs to generate to meet the minimum energy output requirement is 1014.71kW (1,200,000 / (3.24 x 365)). Assuming a collector with an efficiency rating of 21.7%, the minimum required PV area in this example is 4676.10m 2 (1014.71 / (1x 0.217)).

[0046] At step 114, a PV solar system can be designed and constructed at a predetermined location, wherein at least one collector of the PV solar system has at least the minimum required PV area. This step may include determining the number of collectors required based on standard sizes provided by the manufacturer of the selected collector modules. The collector area may exceed the calculated minimum required PV area to account for, for example, failure of a battery within the collector, unexpected surges in consumption, etc.

[0047] In addition to the calculations described above for building a PV solar system, the calculations associated with method 100 can also be used for other purposes, such as economic feasibility studies. For example, using the known minimum required PV area and minimum energy output requirements, annualized cost, levelized cost of energy, energy payback time, etc. can be determined.

[0048] Those skilled in the art will recognize that the boundaries between the above operations are merely illustrative. Multiple operations may be combined into a single operation, a single operation may be distributed among other operations, and operations may be performed with at least partial overlap in time. Furthermore, alternative embodiments may include multiple instances of a particular operation, and the order of the operations may be changed in various other embodiments.

[0049] Although specific and different embodiments are shown in the drawings, various individual elements or combinations of elements from different embodiments may be combined with each other while remaining within the spirit and scope of the present invention. Therefore, a single feature described herein with respect to only one embodiment should not be interpreted as being incompatible with other embodiments described herein or embodiments otherwise encompassed by the present invention.

[0050] Those skilled in the art will appreciate that changes may be made to the above embodiments without departing from the broad inventive concept thereof. It should therefore be understood that the present invention is not limited to the particular embodiments disclosed, but is intended to cover modifications within the spirit and scope of the invention as defined herein.

Claims

1. A method for designing and constructing a photovoltaic (PV) solar energy system at a predetermined location, the PV solar energy system including at least one collector, the method comprising: calculating a daily average typical meteorological year (TMY) insolation value based on TMY data for a predetermined direction of at least one collector of the PV solar energy system; calculating a daily average shading solar insolation loss value at the predetermined location caused by one or more shading obstacles and the predetermined orientation of the at least one collector of the PV solar energy system; Calculate the daily average temperature derating sunshine loss value at the predetermined location; Calculating a daily average effective insolation value for the predetermined position and predetermined direction of the at least one collector of the PV solar energy system by subtracting the daily average shading insolation loss value and the daily average temperature derating insolation loss value from the daily average TMY insolation value; determining a minimum energy output requirement for the PV solar energy system; determining a minimum required PV area of ​​the at least one collector of the PV solar energy system based on the minimum energy output requirement and the average daily effective insolation value; and The PV solar energy system is constructed at the predetermined location with the at least one collector in a predetermined orientation, the at least one collector of the PV solar energy system having at least the minimum required PV area.

2. The method according to claim 1, characterized in that The TMY data includes at least global horizontal irradiance (GHI), direct normal irradiance (DNI) and diffuse horizontal irradiance (DHI) of the latitude and longitude of the predetermined location on at least one selected day of the year and within one or more selected hours of the selected day.

3. The method according to claim 2, characterized in that Calculating the daily average TMY sunshine value includes calculating the direct beam radiation I on the at least one collector BC , diffuse radiation I on at least one collector DC and reflected radiation I on at least one collector RC Add to calculate the at least one collector I C Total radiation on the BC Depends on DNI,I DC Depends on DHI, I RC Depends on GHI.

4. The method according to claim 1, wherein The predetermined orientation of the at least one collector of the PV solar energy system is a fixed orientation, wherein the at least one collector is fixedly facing a single predetermined direction and is fixedly tilted relative to a local horizon at a predetermined collector tilt angle.

5. The method according to claim 1, wherein The predetermined orientation of the at least one collector of the PV solar system is a single axis orbit, wherein the PV solar system moves the at least one collector on a single axis to track the position of the sun in a generally east-west trajectory.

6. The method according to claim 1, characterized in that The predetermined orientation of the at least one collector of the PV solar system is a dual axis orbit, wherein the PV solar system moves the at least one collector in two axes to track the position of the sun in a generally east-west trajectory and a generally north-south trajectory.

7. The method according to claim 1, characterized in that Calculating the daily average shading sunlight loss value includes: determining an azimuth and an elevation of each of the one or more shading obstacles, and One or more time periods are determined by comparing the azimuth and altitude angles of each of the one or more shading obstacles with the path of the sun at the predetermined location during one or more selected hours on at least one selected day of the year, during which at least one collector of the PV solar energy system is blocked by each of the one or more shading obstacles.

8. The method according to claim 1, characterized in that Calculating the daily average temperature derating sunlight loss value is based on at least a nominal operating cell temperature (NOCT) of the at least one collector and an ambient temperature of the predetermined location during one or more selected hours on at least one selected day of the year.

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