Method and device for determining the inclination of a floating photovoltaic system based on the power generated
By determining the installation tilt angle range and calculating the predicted annual total power generation in a floating photovoltaic system, and selecting the tilt angle corresponding to the maximum power generation, the problem of power generation loss in photovoltaic systems in deep-sea environments was solved, thereby maximizing power generation and improving efficiency.
Patent Information
- Authority / Receiving Office
- CN · China
- Patent Type
- Applications(China)
- Current Assignee / Owner
- HUANENG (FUJIAN ZHANG ZHOU) ENERGY CO LTD
- Filing Date
- 2026-03-23
- Publication Date
- 2026-06-23
Smart Images
Figure CN122263418A_ABST
Abstract
Description
Technical Field
[0001] This application relates to the field of floating photovoltaic power generation technology, and more specifically, to a method and apparatus for determining the tilt angle of a floating photovoltaic system based on power generation. Background Technology
[0002] Floating photovoltaic (PV) systems in deep-sea areas represent an emerging application of photovoltaic power generation. Unlike fixed terrestrial PV systems, PV modules are mounted on floating platforms, making the stability of the platform, seawater fluctuations, and shading effects between modules more complex. Current technologies typically rely on onshore experience or simply select a few common angles (such as 5°, 12°, 15°, and 20°) for selecting the installation tilt angle of PV modules on floating platforms, lacking a refined and quantitative method for optimizing tilt angles in the complex marine environment. This empirical selection may prevent the PV system from operating at its optimal power generation state, resulting in power loss. Summary of the Invention
[0003] The purpose of this application is to provide a method and apparatus for determining the tilt angle of a floating photovoltaic system based on power generation, so as to accurately determine the optimal installation tilt angle that maximizes the annual power generation of the floating photovoltaic system under a specific marine environment, thereby effectively improving power generation efficiency.
[0004] In a first aspect, a method for determining the tilt angle of a floating photovoltaic system based on power generation is provided. The floating photovoltaic system includes a floating platform and a photovoltaic module array mounted thereon. The method may include: The floating structure based on the floating platform provides a method for fixing the angle of the photovoltaic module array, which determines the range of the installation tilt angle of the photovoltaic module array; The installation tilt angle range is sequentially divided into multiple discrete candidate tilt angles with a fixed angular step size; each candidate tilt angle has a different angle. For each candidate tilt angle, based on the location data of the floating photovoltaic system, meteorological data, and the arrangement parameters of the photovoltaic module array, the predicted annual total power generation of the photovoltaic module array at that candidate tilt angle is obtained; The candidate tilt angle corresponding to the largest predicted annual total power generation is determined as the target installation tilt angle of the floating photovoltaic system.
[0005] In one possible implementation, the method of fixing the angle of the photovoltaic module array based on the floating structure of the floating platform determines the range of installation tilt angles of the photovoltaic module array, including: The floating structure of the floating platform provides multiple standard installation angle options for the photovoltaic module array; each installation tilt angle option represents a method of fixing the photovoltaic module array at an angle. Identify the minimum and maximum angle values from multiple standard installation tilt options; The continuous closed interval formed by the minimum angle value and the maximum angle value is determined as the installation tilt angle range of the photovoltaic module array.
[0006] In one possible implementation, the installation tilt angle range is sequentially divided into multiple discrete candidate tilt angles with fixed angular steps, including: The starting angle is the lower limit of the aforementioned installation tilt angle range; Using the fixed angle step size as the increment, the angle is continuously accumulated starting from the initial angle, and each accumulation generates an angle value, resulting in an ordered sequence of angle values; the generation process of this angle value sequence continues until the generated angle value reaches or exceeds the upper limit of the installation tilt angle range; All angle values generated within the installation tilt range are determined as multiple discrete candidate tilt angles.
[0007] In one possible implementation, for each candidate tilt angle, based on the location data of the floating photovoltaic system, meteorological data, and the arrangement parameters of the photovoltaic module array, the predicted annual total power generation of the photovoltaic module array at that candidate tilt angle is obtained, including: Based on the location data and meteorological data, the apparent solar motion trajectory and corresponding irradiance variation data for the whole year are obtained; For each candidate tilt angle, perform the following hourly calculation procedure: Based on the aforementioned arrangement parameters, calculate the direct radiation loss caused by shading between the front and rear rows of the photovoltaic module array; Based on the direct radiation loss and the irradiance change data, the hourly effective power generation of the photovoltaic module array after deducting the shading loss is calculated. The hourly effective power generation calculated for all periods throughout the year is summed up to obtain the predicted annual total power generation value corresponding to the candidate tilt angle.
[0008] In one possible implementation, the location data includes the latitude and longitude information of the floating photovoltaic system; The meteorological data includes total solar irradiance, diffuse irradiance, and ambient temperature; The arrangement parameters include the size of the photovoltaic module array and the row and column spacing.
[0009] In one possible implementation, the direct radiation loss due to shading by the front and rear rows of the photovoltaic module array is calculated based on the arrangement parameters, including: Based on the current solar altitude angle and azimuth angle, as well as the row and column spacing of the photovoltaic module array, the size of the photovoltaic modules, and the candidate tilt angle, calculate the proportion of the shadow projection generated by the front row photovoltaic modules on the rear row photovoltaic modules; Multiply the shadow projection ratio by the current direct normal irradiance to obtain the amount of direct radiation lost due to shading.
[0010] In one possible implementation, based on the direct radiation loss and the irradiance variation data, the hourly effective power generation of the photovoltaic module array after deducting shading losses is calculated, including: Calculate the total theoretical irradiance incident on the inclined plane of the photovoltaic module array at the current moment. The total theoretical irradiance includes direct radiation, scattered radiation and reflected radiation components. Convert the total theoretical irradiance into the corresponding theoretical power generation; From the theoretical power generation, the power loss corresponding to the direct radiation lost due to obstruction is deducted to obtain the effective received power after deducting the obstruction loss. The actual output power of the photovoltaic module array is obtained by multiplying the effective received power by the conversion efficiency of the photovoltaic module. The hourly effective power generation is calculated based on the actual output power and the unit calculation time.
[0011] Secondly, a tilt angle determination device for a floating photovoltaic system based on power generation is provided. The floating photovoltaic system includes a floating platform and a photovoltaic module array mounted thereon. The device may include: The determining unit is used to determine the angle fixing method of the photovoltaic module array based on the floating structure of the floating platform, and to determine the installation tilt angle range of the photovoltaic module array; A dividing unit is used to sequentially divide the installation tilt angle range into multiple discrete candidate tilt angles with a fixed angular step size; each candidate tilt angle has a different angle. The acquisition unit is used to obtain the predicted annual total power generation of the photovoltaic module array at each candidate tilt angle based on the location data of the floating photovoltaic system, meteorological data, and the arrangement parameters of the photovoltaic module array. The determining unit is also used to determine the candidate tilt angle corresponding to the largest annual total power generation forecast as the target installation tilt angle of the floating photovoltaic system.
[0012] Thirdly, an electronic device is provided, which includes a processor, a communication interface, a memory, and a communication bus, wherein the processor, the communication interface, and the memory communicate with each other through the communication bus; Memory, used to store computer programs; When a processor executes a program stored in memory, it implements any of the steps described in the first aspect above.
[0013] Fourthly, a computer-readable storage medium is provided, wherein a computer program is stored therein, and when executed by a processor, the computer program implements the steps of any of the methods described in the first aspect above.
[0014] This application provides a method and apparatus for determining the tilt angle of a floating photovoltaic system based on power generation. The floating photovoltaic system includes a floating platform and a photovoltaic module array installed on it. The method, based on the floating structure of the floating platform, determines the installation tilt angle range of the photovoltaic module array by fixing its angle. Then, it sequentially divides the installation tilt angle range into multiple discrete candidate tilt angles with a fixed angle step size. Each candidate tilt angle has a different angle. For each candidate tilt angle, based on the location data of the floating photovoltaic system, meteorological data, and the arrangement parameters of the photovoltaic module array, it obtains the predicted annual total power generation value of the photovoltaic module array at that candidate tilt angle. The candidate tilt angle corresponding to the largest predicted annual total power generation value is determined as the target installation tilt angle of the floating photovoltaic system. This method, through systematic searching and precise quantification of dynamic shading loss within the entire physically feasible tilt angle range, can determine the optimal installation tilt angle that maximizes the annual power generation of the floating photovoltaic system at a specific site, thereby effectively improving power generation efficiency. Attached Figure Description
[0015] To more clearly illustrate the technical solutions of the embodiments of this application, the accompanying drawings used in the embodiments of this application will be briefly introduced below. It should be understood that the following drawings only show some embodiments of this application and should not be regarded as a limitation of the scope. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.
[0016] Figure 1 A flowchart illustrating a method for determining the tilt angle of a floating photovoltaic system based on power generation, provided in an embodiment of this application; Figure 2 A schematic diagram of the tilt angle determination device for a floating photovoltaic system based on power generation is provided in an embodiment of this application; Figure 3 This is a schematic diagram of the structure of an electronic device provided in an embodiment of this application. Detailed Implementation
[0017] The technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments of this application, and not all of the embodiments. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application. Unless otherwise defined, the technical or scientific terms used in this application should have the ordinary meaning understood by those skilled in the art. The words "first," "second," and similar terms used in this application do not indicate any order, quantity, or importance, but are only used to distinguish different components. The words "comprising" or "including," etc., mean that the element or object preceding the word covers the element or object listed after the word and its equivalents, but do not exclude other elements or objects. The words "connected," "coupled," or "connected," etc., are not limited to physical or mechanical connections, but can include electrical connections, whether direct or indirect. "Up," "down," "left," "right," etc., are only used to indicate relative positional relationships. When the absolute position of the described object changes, the relative positional relationship may also change accordingly.
[0018] The tilt angle determination method for floating photovoltaic systems based on power generation provided in this application, through systematic simulation search and innovative optimization strategies, accurately quantifies the power generation loss caused by internal shading of the array at different tilt angles within a physically feasible continuous tilt angle range, thereby determining the optimal installation tilt angle that maximizes the total annual power generation. This method is applicable to solving the complex shading problem caused by platform fluctuations and dense array arrangement in deep-sea environments.
[0019] This application presents a method for determining the tilt angle of a floating photovoltaic (PV) system based on power generation. This system is based on a typical floating PV system, which mainly comprises a floating platform and a PV module array. The PV module array is fixedly installed on the floating platform via a support structure. The floating structure of the floating platform (usually referring to the main floating body) has its support surface angle pre-set during manufacturing, thus determining the achievable installation tilt angle of the PV module array. Most mainstream floating body products on the market typically offer several standard tilt angle options, such as 5°, 12°, 15°, and 20°. Before implementing this application, the following basic parameters need to be collected and prepared: Site parameters: The precise latitude and longitude of the sea area where the floating photovoltaic system is planned to be deployed, i.e., the location data of the floating photovoltaic system.
[0020] Meteorological data: Typical meteorological year data, which may include total solar radiation irradiance, diffuse radiation irradiance, ambient temperature, etc.
[0021] Layout parameters of photovoltaic module array: the size (length and width) of the selected photovoltaic modules, the layout diagram of the entire photovoltaic module array (including the number of rows and columns), and the row and column spacing (especially the north-south spacing, which is a key parameter affecting shading).
[0022] Floating body product parameters: Investigate and determine the standard installation tilt angle options supported by the available floating body products.
[0023] The preferred embodiments of this application are described below with reference to the accompanying drawings. It should be understood that the preferred embodiments described herein are for illustration and explanation only and are not intended to limit this application. Furthermore, the embodiments and features in the embodiments of this application can be combined with each other without conflict.
[0024] Figure 1 This is a flowchart illustrating a method for determining the tilt angle of a floating photovoltaic system based on power generation, provided in an embodiment of this application. Figure 1 As shown, the method may include: Step S110: Based on the angle fixing method of the photovoltaic module array provided by the floating structure of the floating platform, determine the installation tilt angle range of the photovoltaic module array.
[0025] The installation tilt angle range is a continuous angular interval allowed by the floating structure.
[0026] First, obtain multiple standard installation angle options (e.g., 5°, 12°, 15°, 20°) for the photovoltaic module array provided by the floating structure of the floating platform; each installation tilt angle option represents a specific embodiment of an angle fixing method for the photovoltaic module array.
[0027] Subsequently, the minimum angle value (e.g., 5°) and the maximum angle value (e.g., 20°) are identified from a plurality of discrete standard mounting tilt angle options. Finally, the continuous closed interval [5°, 20°] formed by the minimum angle value and the maximum angle value is determined as the installation tilt angle range of the photovoltaic module array optimized in this study. This range represents the physically achievable continuous angle range that current floating body manufacturing technology can support.
[0028] The specific implementation of this step expands the starting point of the optimization search from a finite set of discrete points to a continuous physically feasible interval, ensuring that the optimal solution exists in the search space and providing the possibility of discovering non-standard optimal tilt angles (such as 11°).
[0029] Step S120: Divide the installation tilt angle range into multiple discrete candidate tilt angles in sequence with a fixed angle step size.
[0030] The angles of each candidate tilt angle are different.
[0031] Option 1: Starting with the lower limit of the installation tilt angle range (5°), the angle is continuously accumulated from the starting angle using a fixed angle step size (preferably 1°). Each accumulation generates an angle value, resulting in an ordered sequence of angle values. This generation process continues until the generated angle values reach or exceed the upper limit of the installation tilt angle range. Finally, all angle values generated within the installation tilt angle range are identified as multiple discrete candidate tilt angles. Specifically, starting with a fixed angle step size (preferably 1°), continuous accumulation is performed until the generated angle values reach or exceed the upper limit of the installation tilt angle range (20°). This ultimately generates an ordered sequence of angle values (i.e., 5°, 6°, 7°, ..., 19°, 20°) as multiple discrete candidate tilt angles.
[0032] Scheme 1 achieves a systematic and comprehensive scan of continuous intervals by generating a simple arithmetic sequence. The 1° step size achieves a good balance between ensuring calculation accuracy (effectively distinguishing the difference in power generation between 11° and 10° or 12°) and calculation efficiency (controllable number of calculations, a total of 16 calculations within the 5°-20° interval).
[0033] Option 2, to further improve search efficiency, involves non-uniformly dividing the installation tilt angle range based on the latitude information of the floating photovoltaic system. Specifically, this includes: First, based on latitude information, the theoretical value of the annual optimal tilt angle for the region is estimated using classical empirical formulas (for example, the estimated value is approximately the latitude multiplied by 0.87 plus a constant).
[0034] Subsequently, a fine search interval (e.g., theoretical value ± 3°) is established near this theoretical value of inclination. Within this interval, a small first fine step size (e.g., 0.5°) is used for division to perform a high-precision search.
[0035] Then, for the area outside the fine search interval, a larger second regular step size (e.g., 2°) is used for subdivision to quickly cover other areas.
[0036] Finally, following the strategy described above, a set of candidate tilt angles is generated across the entire installation tilt angle range.
[0037] Scheme 2 intelligently divides the search interval into non-uniform regions by introducing prior knowledge of latitude and optimal tilt angle. It performs a fine-grained search in areas where the optimal solution has a high probability of occurrence, while coarsely screening other areas. This significantly reduces the number of simulation calculations and improves the computational efficiency of large-scale optimization problems without substantially sacrificing optimization accuracy.
[0038] Step S130: For each candidate tilt angle, based on the location data of the floating photovoltaic system, meteorological data, and the arrangement parameters of the photovoltaic module array, obtain the predicted value of the annual total power generation of the photovoltaic module array under the candidate tilt angle.
[0039] Before performing the final step, i.e., before conducting detailed calculations for a candidate tilt angle, a preliminary judgment is made. Specifically: based on the row and column spacing and photovoltaic module size in the layout parameters, a quick determination is made based on geometric relationships (such as calculations using data from the winter solstice when the solar altitude angle is lowest) to determine whether there will necessarily be unacceptable persistent shading at any candidate tilt angle (e.g., shadows completely covering the rear rows of modules). If the determination is yes, the detailed calculation for that candidate tilt angle is skipped, and a preset minimum power generation prediction value is directly assigned to that candidate tilt angle.
[0040] The geometric relationship refers to the relationship between the height (H) of the photovoltaic module in the tilted state and the row spacing (D) in the north-south direction of the photovoltaic module array. Specifically, the shading situation is determined by comparing the theoretical projection distance (L, i.e., the maximum length of the shadow) of the highest point of the front row photovoltaic module on the plane where the lowest point of the rear row photovoltaic module is located under a specific solar position (such as noon on the winter solstice) with the actual row spacing (D).
[0041] The following geometric parameters are required to calculate geometric relations: H (Critical Height): This refers to the vertical height difference between the highest edge and the lowest edge of a photovoltaic module when it is installed at a candidate tilt angle (β). It is not a fixed value, but a variable that increases with the tilt angle β. The calculation formula is: H = Module Length × sin(β).
[0042] D (row spacing): The center-to-center distance between two rows of photovoltaic modules in a photovoltaic module array, in the north-south direction. This is a fixed arrangement parameter.
[0043] α (Solar altitude angle): In preliminary assessments, the lowest solar altitude angle of the year is usually selected, namely the solar altitude angle at noon on the winter solstice. This is a fixed value based on the site's latitude, representing the worst solar conditions (longest shadow).
[0044] Calculate the theoretical maximum shadow length (L): At noon on the winter solstice, when the height of the front row of components is H, the theoretical length of its shadow on the horizontal plane is L=H / tan(α).
[0045] If the calculated shadow length L ≥ the actual row spacing D, it means that under the worst sunshine conditions, the shadow of the front-row components completely covers the rear-row components, and the rear-row components cannot receive any direct radiation. There is unacceptable persistent shadow occlusion at this candidate inclination angle. If L < D, it means that even on the winter solstice, there is still a part of the rear-row components that can receive sunlight, and this inclination angle is worthy of subsequent detailed power generation simulation.
[0046] The above pre-screening process can quickly identify and eliminate those invalid candidate inclination angles that will inevitably lead to extremely poor power generation performance due to geometric reasons, avoiding time-consuming detailed simulations for these obviously uncompetitive schemes, saving a large amount of computing resources, especially suitable for scenarios with a large initial range or a dense step size, and improving the overall optimization efficiency.
[0047] Return to step S130, specifically: Based on the location data and meteorological data, obtain the annual solar apparent motion trajectory (i.e., the solar altitude angle and azimuth angle at each moment) and the corresponding irradiance change data; for each candidate inclination angle, perform the following hourly calculation process for 8760 hours (or a shorter time step) throughout the year: (1) According to the layout parameters, calculate the direct radiation loss caused by the occlusion between the front and rear rows of the photovoltaic module array. Specifically: Based on the solar altitude angle and azimuth angle at the current moment, as well as the row and column spacing of the photovoltaic module array, the size of the photovoltaic module, and the candidate inclination angle, calculate the shadow projection ratio of the front-row photovoltaic modules on the rear-row photovoltaic modules; Multiply the shadow projection ratio by the direct normal irradiance at the current moment to obtain the direct radiation loss due to occlusion.
[0048] Furthermore, the dynamic pitch and roll angles of the platform caused by waves can be considered.
[0049] Superimpose the dynamic attitude angles of the platform with the solar incidence angle and the candidate inclination angle, calculate the actual effective light-receiving area of the rear-row photovoltaic modules under dynamic sea conditions, and then determine a more accurate direct radiation loss.
[0050] In an example, the shadow losses in two cases, without considering the platform attitude (static model) and considering the platform attitude (dynamic model), will be calculated respectively.
[0051] Case 1, static model (assuming calm sea surface and the platform does not move) According to the solar altitude angle (30°), azimuth angle (180°), candidate inclination angle (15°), and row spacing (4 meters), calculate through geometric projection. Assume that it is calculated that 25% of the area of the rear-row components is occluded by the shadow of the front-row components at this time. The static shadow projection ratio S_static = 25%.
[0052] Calculate the direct radiation loss: Direct radiation loss = S_static × DNI = 25% × 700 W / m² = 175 W / m².
[0053] Scenario 2, Dynamic Model (Platform Motion) The core of dynamic calculation is coordinate transformation. We need to transform the direction vector of the sunlight into the platform coordinate system, which sways along with the platform.
[0054] In a static ground coordinate system, the direction vector of sunlight is fixed. However, due to the platform's pitch (+4°) and roll (-2°), the orientation of the photovoltaic module plane has changed. By calculating using a rotation matrix, the solar vector is transformed to the platform coordinate system, yielding the equivalent solar angle in the platform coordinate system: Equivalent solar altitude angle: Since the bow of the ship is raised (+4°) directly towards the sun, the sun appears to be higher. The calculated equivalent altitude angle is approximately 33.5°.
[0055] Equivalent solar azimuth: Due to the downward tilt on the right (-2°), the sun appears to be slightly tilted to the left (east). The calculated equivalent azimuth is approximately 181.5°.
[0056] Geometric projection is performed using the equivalent solar altitude angle (33.5°), equivalent solar azimuth angle (181.5°), candidate tilt angle (15°), and line spacing (4 meters). As the equivalent solar altitude angle increases, the shadow length will shorten. Assume the calculated dynamic shadow projection ratio S_dynamic = 18%.
[0057] Calculate the dynamic direct radiation loss: Dynamic direct radiation loss = S_dynamic × DNI = 18% × 700 W / m² = 126 W / m².
[0058] In other words, the waves caused the platform's bow to rise and tilt to the right, improving the sunlight's incidence conditions in the platform's coordinate system (increasing the equivalent solar altitude angle). This resulted in: reduced shadow shading (the shadow projection ratio decreased from 25% to 18%) and reduced radiation loss (direct radiation loss decreased from 175W / m² to 126W / m², a difference of 49W / m²).
[0059] (2) Based on the data of direct radiation loss and irradiance variation, calculate the hourly effective power generation of the photovoltaic module array after deducting shading losses, specifically including the following steps: 1) Calculate the total theoretical irradiance (including direct radiation, diffuse radiation, and ground / sea surface reflected radiation components) incident on the inclined surface of the photovoltaic module at the current tilt angle, without considering shading. That is, calculate the total theoretical irradiance incident on the inclined surface of the photovoltaic module array at the current moment, which includes direct radiation, diffuse radiation, and reflected radiation components. Specifically, classic inclined surface irradiance models (such as the Hay model, Perez model, etc.) can be used for calculation, which will not be elaborated upon here.
[0060] 2) Convert the total theoretical irradiance into the corresponding theoretical power generation. Specifically: Obtain the total theoretical irradiance (W / m²) and the total area of the photovoltaic module array (m²) obtained above. Then, calculate the theoretical power generation (P_theoretical): P_theoretical = Total theoretical irradiance × Total area of photovoltaic module array. P_theoretical represents the maximum instantaneous light power that the entire photovoltaic array can receive under ideal conditions, assuming no energy loss (including shading loss and conversion loss). Its unit is watt (W).
[0061] 3) Subtract the power loss corresponding to the direct radiation lost due to shading from the theoretical power generation to obtain the effective received power after deducting the shading loss. Total power loss P_loss_total: Extends the direct radiation loss per unit area to the entire array area: P_loss_total = direct radiation loss × total area of photovoltaic module array. This direct radiation loss specifically refers to the portion lost due to shading.
[0062] Effective received power: The total power loss is deducted from the theoretical power generation: P_effective = P_theoretical - P_loss_total.
[0063] P_effective represents the actual light power that shines on the photovoltaic module cells and can be used for photoelectric conversion after deducting shading losses.
[0064] 4) Multiply the effective received power by the conversion efficiency of the photovoltaic module to obtain the actual output power of the photovoltaic module array. Specifically: the product of the effective received power (P_effective) and the conversion efficiency η of the photovoltaic module is determined as the actual output power (P_output), in watts (W), where η is a value between 0 and 1, for example, a typical value of about 0.18-0.22 for monocrystalline silicon modules.
[0065] 5) Based on the actual output power and the unit calculation time, the hourly effective power generation is calculated. This step converts the instantaneous power into the total electrical energy generated over a period of time (one hour). Assuming that solar irradiance and shading are relatively stable within a one-hour time step, the power value can be considered constant. Then, the power generation (E_hourly) is calculated by multiplying the power by the time, i.e., E_hourly = P_output × 1h.
[0066] (3) The hourly effective power generation calculated for all periods throughout the year is summed up to obtain the annual total power generation prediction value corresponding to the candidate tilt angle, that is, the annual total power generation prediction value of the photovoltaic module array under the candidate tilt angle.
[0067] This step, through hourly, dynamic shading calculations and power generation deduction, achieves precise quantification of the most complex nonlinear factor (shading) in the "tilt angle-power generation" relationship. The static model already significantly outperforms empirical methods, while the dynamic model goes a step further, making the power generation prediction results closer to the actual operating conditions of deep-sea photovoltaic arrays under real wave conditions, greatly improving the accuracy of the optimization results and their engineering guidance value.
[0068] Step S140: Determine the candidate tilt angle corresponding to the largest annual total power generation forecast as the target installation tilt angle for the floating photovoltaic system.
[0069] Each candidate tilt angle is paired with its corresponding annual total power generation forecast to form a set of data pairs. For example, (5°,E5), (6°,E6), ..., (20°,E20).
[0070] Sort the annual total power generation forecasts (E5 to E20) in all data pairs (e.g., in descending order) and identify the maximum value (Emax).
[0071] The candidate tilt angle corresponding to this maximum value (Emax) is the determined optimal installation tilt angle.
[0072] In some embodiments, after the floating photovoltaic system is actually operating at the determined optimal installation tilt angle, a feedback optimization loop may be further initiated: Continuously collect actual power generation data for at least one full year of actual system operation.
[0073] The actual power generation data is compared with the annual total power generation forecast obtained in step S130, and the relative deviation is calculated.
[0074] If the relative deviation continues to exceed a preset threshold (e.g., 5%), it indicates that the environmental conditions have changed significantly. In this case, the tilt angle determination method of this application is automatically triggered to optimize the tilt angle. That is, based on the latest actual data, the complete process of the tilt angle determination method of this application is re-executed to determine the new optimal installation tilt angle under the new boundary conditions or environmental parameters.
[0075] The feedback optimization mechanism introduced by this approach transforms this application from a one-off design tool into a system-level optimization strategy with self-learning and adaptive capabilities. It can cope with environmental changes and model errors, maintain the photovoltaic power generation system in optimal operating condition over the long term, and achieve full life-cycle performance management.
[0076] The method described in this application, through systematic and refined searching and simulation across the entire physically feasible tilt angle range, can accurately pinpoint the optimal installation tilt angle that maximizes the total annual power generation of a floating photovoltaic system at a specific site. This method overcomes the limitations of traditional methods that rely on limited experience or standard angle selection, avoiding power generation losses due to improper tilt angle selection, thereby directly improving the project's power generation efficiency and economic returns.
[0077] Corresponding to the above method, this application also provides a tilt angle determination device for a floating photovoltaic system based on power generation, such as... Figure 2 As shown, the device includes: The determining unit 210 is used to determine the angle fixing method of the photovoltaic module array based on the floating structure of the floating platform, and to determine the installation tilt angle range of the photovoltaic module array. The dividing unit 220 is used to sequentially divide the installation tilt angle range into multiple discrete candidate tilt angles with a fixed angular step size; each candidate tilt angle has a different angle. The acquisition unit 230 is used to acquire the predicted annual total power generation of the photovoltaic module array at each candidate tilt angle based on the location data of the floating photovoltaic system, meteorological data and the arrangement parameters of the photovoltaic module array. The determining unit 210 is also used to determine the candidate tilt angle corresponding to the largest annual total power generation forecast as the target installation tilt angle of the floating photovoltaic system.
[0078] The functions of each functional unit in the tilt angle determination device for a floating photovoltaic system based on power generation provided in the above embodiments of this application can be implemented through the above-described method steps. Therefore, the specific working process and beneficial effects of each unit in the tilt angle determination device for a floating photovoltaic system based on power generation provided in the embodiments of this application will not be repeated here.
[0079] This application also provides an electronic device, such as... Figure 3As shown, it includes a processor 310, a communication interface 320, a memory 330, and a communication bus 340, wherein the processor 310, the communication interface 320, and the memory 330 communicate with each other through the communication bus 340.
[0080] Memory 330 is used to store computer programs; When the processor 310 executes the program stored in the memory 330, it performs the following steps: The floating structure based on the floating platform provides a method for fixing the angle of the photovoltaic module array, which determines the range of the installation tilt angle of the photovoltaic module array; The installation tilt angle range is sequentially divided into multiple discrete candidate tilt angles with a fixed angular step size; each candidate tilt angle has a different angle. For each candidate tilt angle, based on the location data of the floating photovoltaic system, meteorological data, and the arrangement parameters of the photovoltaic module array, the predicted annual total power generation of the photovoltaic module array at that candidate tilt angle is obtained; The candidate tilt angle corresponding to the largest predicted annual total power generation is determined as the target installation tilt angle of the floating photovoltaic system.
[0081] The communication bus mentioned above can be a Peripheral Component Interconnect (PCI) bus or an Extended Industry Standard Architecture (EISA) bus, etc. This communication bus can be divided into address bus, data bus, control bus, etc. For ease of illustration, only one thick line is used to represent it in the diagram, but this does not mean that there is only one bus or one type of bus.
[0082] The communication interface is used for communication between the aforementioned electronic devices and other devices.
[0083] The memory may include random access memory (RAM) or non-volatile memory (NVM), such as at least one disk storage device. Optionally, the memory may also be at least one storage device located remotely from the aforementioned processor.
[0084] The processors mentioned above can be general-purpose processors, including central processing units (CPUs), network processors (NPs), etc.; they can also be digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, or discrete hardware components.
[0085] The implementation methods and beneficial effects of the various components of the electronic device in the above embodiments for solving the problem can be found in [reference needed]. Figure 1 The steps in the illustrated embodiments are used to implement the electronic device. Therefore, the specific working process and beneficial effects of the electronic device provided in this application will not be repeated here.
[0086] In another embodiment provided in this application, a computer-readable storage medium is also provided, which stores instructions that, when executed on a computer, cause the computer to perform the tilt angle determination method for a floating photovoltaic system based on power generation as described in any of the above embodiments.
[0087] In another embodiment provided in this application, a computer program product containing instructions is also provided, which, when run on a computer, causes the computer to execute the tilt angle determination method for a floating photovoltaic system based on power generation as described in any of the above embodiments.
[0088] Those skilled in the art will understand that the embodiments in this application can be provided as methods, systems, or computer program products. Therefore, the embodiments in this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the embodiments in this application can take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.
[0089] This application describes embodiments of methods, apparatus (systems), and computer program products according to embodiments of this application with reference to flowchart illustrations and / or block diagrams. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.
[0090] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.
[0091] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.
[0092] Although preferred embodiments have been described in this application, those skilled in the art, upon learning the basic inventive concept, can make other changes and modifications to these embodiments. Therefore, the appended claims are intended to be interpreted as including the preferred embodiments as well as all changes and modifications falling within the scope of the embodiments of this application.
[0093] Obviously, those skilled in the art can make various modifications and variations to the embodiments of this application without departing from the spirit and scope of the embodiments of this application. Therefore, if these modifications and variations to the embodiments of this application fall within the scope of the claims in this application and their equivalents, then this application also intends to include these modifications and variations.
Claims
1. A method for determining the tilt angle of a floating photovoltaic system based on power generation, the floating photovoltaic system comprising a floating platform and a photovoltaic module array mounted thereon, characterized in that, The method includes: The floating structure based on the floating platform provides a method for fixing the angle of the photovoltaic module array, which determines the range of the installation tilt angle of the photovoltaic module array; The installation tilt angle range is sequentially divided into multiple discrete candidate tilt angles with a fixed angular step size; each candidate tilt angle has a different angle. For each candidate tilt angle, based on the location data of the floating photovoltaic system, meteorological data, and the arrangement parameters of the photovoltaic module array, the predicted annual total power generation of the photovoltaic module array at that candidate tilt angle is obtained; The candidate tilt angle corresponding to the largest predicted annual total power generation is determined as the target installation tilt angle of the floating photovoltaic system.
2. The method as described in claim 1, characterized in that, The floating structure based on a floating platform provides a method for fixing the angle of the photovoltaic module array, determining the range of installation tilt angles for the photovoltaic module array, including: The floating structure of the floating platform provides multiple standard installation angle options for the photovoltaic module array; each installation tilt angle option represents a method of fixing the photovoltaic module array at an angle. Identify the minimum and maximum angle values from multiple standard installation tilt options; The continuous closed interval formed by the minimum angle value and the maximum angle value is determined as the installation tilt angle range of the photovoltaic module array.
3. The method as described in claim 1, characterized in that, The installation tilt angle range is sequentially divided into multiple discrete candidate tilt angles using a fixed angular step size, including: The starting angle is the lower limit of the aforementioned installation tilt angle range; Using the fixed angle step size as the increment, the angle is continuously accumulated starting from the initial angle, and each accumulation generates an angle value, resulting in an ordered sequence of angle values; the generation process of this angle value sequence continues until the generated angle value reaches or exceeds the upper limit of the installation tilt angle range; All angle values generated within the installation tilt range are determined as multiple discrete candidate tilt angles.
4. The method as described in claim 1, characterized in that, For each candidate tilt angle, based on the location data of the floating photovoltaic system, meteorological data, and the arrangement parameters of the photovoltaic module array, the predicted annual total power generation of the photovoltaic module array at that candidate tilt angle is obtained, including: Based on the location data and meteorological data, the apparent solar motion trajectory and corresponding irradiance variation data for the whole year are obtained; For each candidate tilt angle, perform the following hourly calculation procedure: Based on the aforementioned arrangement parameters, calculate the direct radiation loss caused by shading between the front and rear rows of the photovoltaic module array; Based on the direct radiation loss and the irradiance change data, the hourly effective power generation of the photovoltaic module array after deducting the shading loss is calculated. The hourly effective power generation calculated for all periods throughout the year is summed up to obtain the predicted annual total power generation value corresponding to the candidate tilt angle.
5. The method as described in claim 4, characterized in that, The location data includes the latitude and longitude information of the floating photovoltaic system; The meteorological data includes total solar irradiance, diffuse irradiance, and ambient temperature; The arrangement parameters include the size of the photovoltaic module array and the row and column spacing.
6. The method as described in claim 5, characterized in that, Based on the aforementioned arrangement parameters, calculate the direct radiation loss caused by shading between the front and rear rows of the photovoltaic module array, including: Based on the current solar altitude angle and azimuth angle, as well as the row and column spacing of the photovoltaic module array, the size of the photovoltaic modules, and the candidate tilt angle, calculate the proportion of the shadow projection generated by the front row photovoltaic modules on the rear row photovoltaic modules; Multiply the shadow projection ratio by the current direct normal irradiance to obtain the amount of direct radiation lost due to shading.
7. The method as described in claim 6, characterized in that, Based on the direct radiation loss and the irradiance variation data, the hourly effective power generation of the photovoltaic module array after deducting shading losses is calculated, including: Calculate the total theoretical irradiance incident on the inclined plane of the photovoltaic module array at the current moment. The total theoretical irradiance includes direct radiation, scattered radiation and reflected radiation components. Convert the total theoretical irradiance into the corresponding theoretical power generation; From the theoretical power generation, the power loss corresponding to the direct radiation lost due to obstruction is deducted to obtain the effective received power after deducting the obstruction loss. The actual output power of the photovoltaic module array is obtained by multiplying the effective received power by the conversion efficiency of the photovoltaic module. The hourly effective power generation is calculated based on the actual output power and the unit calculation time.
8. A tilt angle determination device for a floating photovoltaic system based on power generation, the floating photovoltaic system comprising a floating platform and a photovoltaic module array mounted thereon, characterized in that, The device includes: The determining unit is used to determine the angle fixing method of the photovoltaic module array based on the floating structure of the floating platform, and to determine the installation tilt angle range of the photovoltaic module array; A dividing unit is used to sequentially divide the installation tilt angle range into multiple discrete candidate tilt angles with a fixed angular step size; each candidate tilt angle has a different angle. The acquisition unit is used to obtain the predicted annual total power generation of the photovoltaic module array at each candidate tilt angle based on the location data of the floating photovoltaic system, meteorological data, and the arrangement parameters of the photovoltaic module array. The determining unit is also used to determine the candidate tilt angle corresponding to the largest annual total power generation forecast as the target installation tilt angle of the floating photovoltaic system.
9. An electronic device, characterized in that, The electronic device includes a processor, a communication interface, a memory, and a communication bus, wherein the processor, the communication interface, and the memory communicate with each other through the communication bus; Memory, used to store computer programs; A processor, when executing a program stored in memory, implements the method of any one of claims 1-7.
10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that, when executed by a processor, implements the method described in any one of claims 1-7.