Pub Date : 2026-07-01Epub Date: 2026-03-31DOI: 10.1109/JPHOTOV.2026.3668778
S. Poddar;S. Liu;P. Hamer;M. Kay;B. Hoex
Ultraviolet (UV) radiation accelerates the degradation of photovoltaic (PV) modules, both at the cell and module levels, leading to reduced efficiency and a shorter lifespan. While reliability testing has advanced, current standards often fail to reflect real-world UV exposure, especially across diverse climates. Global UV irradiance varies widely, from <30>2 in high-latitude regions to >80 W/m2 in arid zones, while standard tests such as IEC-61215 only test up to a dose of 15 kWh /m2 that can be reached in less than 50 days in some locations. This study develops a high-precision model to estimate UV radiation on tilted surfaces and assesses the influence on UV photodegradation. The model shows minimum bias (<±3.87>2, i.e., <±4.28% ) when compared with observations. Results show notable global variation in UV irradiance on tilted surfaces between single-axis tracking (SAT) and fixed-tilt systems, hence affecting degradation rates. SAT systems experience approximately twice the degradation in arid and semi-arid climates compared to fixed-tilt systems, where UV exposure is most intense. These findings highlight the critical need for climate-specific degradation assessments even for identical module technologies. To ensure outdoor durability and long-term performance, advanced regionally adaptive reliability testing thresholds should be adapted for better-informed material selection and manufacturing.
{"title":"Closing the UV-Induced Photodegradation Gap Through Global Scale Modeling of Fixed Tilt and Tracking Photovoltaic Systems","authors":"S. Poddar;S. Liu;P. Hamer;M. Kay;B. Hoex","doi":"10.1109/JPHOTOV.2026.3668778","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2026.3668778","url":null,"abstract":"Ultraviolet (UV) radiation accelerates the degradation of photovoltaic (PV) modules, both at the cell and module levels, leading to reduced efficiency and a shorter lifespan. While reliability testing has advanced, current standards often fail to reflect real-world UV exposure, especially across diverse climates. Global UV irradiance varies widely, from <30>2</sup> in high-latitude regions to >80 W/m<sup>2</sup> in arid zones, while standard tests such as IEC-61215 only test up to a dose of 15 kWh /m<sup>2</sup> that can be reached in less than 50 days in some locations. This study develops a high-precision model to estimate UV radiation on tilted surfaces and assesses the influence on UV photodegradation. The model shows minimum bias (<±3.87>2</sup>, i.e., <±4.28% ) when compared with observations. Results show notable global variation in UV irradiance on tilted surfaces between single-axis tracking (SAT) and fixed-tilt systems, hence affecting degradation rates. SAT systems experience approximately twice the degradation in arid and semi-arid climates compared to fixed-tilt systems, where UV exposure is most intense. These findings highlight the critical need for climate-specific degradation assessments even for identical module technologies. To ensure outdoor durability and long-term performance, advanced regionally adaptive reliability testing thresholds should be adapted for better-informed material selection and manufacturing.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"16 4","pages":"494-503"},"PeriodicalIF":3.7,"publicationDate":"2026-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148517457","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-07-01Epub Date: 2026-03-14DOI: 10.1109/JPHOTOV.2026.3687914
Steve Johnston;Ryan Ruhle;Dana B. Kern;Kent Terwilliger;David Durney;Walajabad Sampath
Lamination-free minimodules are constructed with silicon solar cells between glass sheets and an edge seal of polyisobutylene and silicone. These samples are stressed using a repeated sequential testing sequence including ultraviolet-containing simulated solar spectrum light exposure at elevated temperature, damp heat, humidity freeze, and thermal cycling adapted from the International Electrotechnical Commission (IEC) TS 63209-2:2022. The minimodule performance throughout the stressing is characterized by flash testing and electroluminescence imaging. Results are compared to conventional laminated minimodules using the same type of solar cells. The lamination-free minimodules experience up to 8% power loss compared to roughly 3% for the laminated versions. However, those losses, dominated by current and fill factor, are caused by glass soiling and busbar ribbon separation on the cells. When glass is replaced and the stressed cells are contacted with probes bypassing the delaminated ribbons, the initial performance is recovered, and overall losses of the lamination-free samples become negligible.
{"title":"Extended Accelerated Stress Testing of Lamination-Free Edge-Sealed Photovoltaic Minimodules","authors":"Steve Johnston;Ryan Ruhle;Dana B. Kern;Kent Terwilliger;David Durney;Walajabad Sampath","doi":"10.1109/JPHOTOV.2026.3687914","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2026.3687914","url":null,"abstract":"Lamination-free minimodules are constructed with silicon solar cells between glass sheets and an edge seal of polyisobutylene and silicone. These samples are stressed using a repeated sequential testing sequence including ultraviolet-containing simulated solar spectrum light exposure at elevated temperature, damp heat, humidity freeze, and thermal cycling adapted from the International Electrotechnical Commission (IEC) TS 63209-2:2022. The minimodule performance throughout the stressing is characterized by flash testing and electroluminescence imaging. Results are compared to conventional laminated minimodules using the same type of solar cells. The lamination-free minimodules experience up to 8% power loss compared to roughly 3% for the laminated versions. However, those losses, dominated by current and fill factor, are caused by glass soiling and busbar ribbon separation on the cells. When glass is replaced and the stressed cells are contacted with probes bypassing the delaminated ribbons, the initial performance is recovered, and overall losses of the lamination-free samples become negligible.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"16 4","pages":"504-508"},"PeriodicalIF":3.7,"publicationDate":"2026-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148519016","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-07-01Epub Date: 2026-04-29DOI: 10.1109/JPHOTOV.2026.3684067
Walker S. Arce;Kelly Schutt;Joseph Luther;Karen Stelling
When developing systems for perovskite solar cells (PSCs), it is important to have a testing platform that closely resembles your deployed systems. While developing a 1 U CubeSat, the Big Red Sat-1 at the University of Nebraska-Lincoln, we found a lack of passive curve tracing instrumentation, which we needed for our mission. To that end, we developed a benchtop passive curve tracer that leverages the Ossila Solar Simulator as an AM1.5 light source. This device utilizes a ladder of switched resistors and a precision voltage and current measurement to achieve the curve tracing. It also integrates a common-anode multiplexer to switch through multipixel PSCs. Finally, the solar cell holder is separate from the main measurement system, so various substrates sizes and pixel counts can be supported. This system is tested using various PSCs. It has been open sourced to enable reuse in future systems that may benefit from the lower power consumption and flight heritage.
{"title":"An Open Source Perovskite Solar Cell Curve Tracer","authors":"Walker S. Arce;Kelly Schutt;Joseph Luther;Karen Stelling","doi":"10.1109/JPHOTOV.2026.3684067","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2026.3684067","url":null,"abstract":"When developing systems for perovskite solar cells (PSCs), it is important to have a testing platform that closely resembles your deployed systems. While developing a 1 U CubeSat, the Big Red Sat-1 at the University of Nebraska-Lincoln, we found a lack of passive curve tracing instrumentation, which we needed for our mission. To that end, we developed a benchtop passive curve tracer that leverages the Ossila Solar Simulator as an AM1.5 light source. This device utilizes a ladder of switched resistors and a precision voltage and current measurement to achieve the curve tracing. It also integrates a common-anode multiplexer to switch through multipixel PSCs. Finally, the solar cell holder is separate from the main measurement system, so various substrates sizes and pixel counts can be supported. This system is tested using various PSCs. It has been open sourced to enable reuse in future systems that may benefit from the lower power consumption and flight heritage.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"16 4","pages":"428-433"},"PeriodicalIF":3.7,"publicationDate":"2026-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148518765","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-07-01Epub Date: 2026-04-08DOI: 10.1109/JPHOTOV.2026.3677506
Kevin S. Anderson;Adam R. Jensen;Clifford W. Hansen
Simulation models used to develop and finance bifacial photovoltaic systems estimate rear-side irradiance using 2-D view factor models. These models make simplifying assumptions that do not account for complexities—such as sloped terrain and nonuniform ground albedo—found in modern photovoltaic systems. In this work, we describe ANTS-2D, a new, computationally efficient 2-D view factor model for computing front- and rear-side irradiance across the module surface, considering both nonuniformity in ground albedo and sloped terrain. For the base case of a horizontal and uniform ground surface, we show that the model's accuracy relative to a ray-tracing model baseline is within approximately 1 W m$^{-2}$ of the best available alternative view factor model while also featuring an 85% reduction in computation time. The model also allows for detailed ground irradiances, particularly useful for agrivoltaic applications.
用于开发和资助双面光伏系统的仿真模型使用二维视图因子模型估计后侧辐照度。这些模型做出了简化的假设，没有考虑到现代光伏系统中存在的复杂性，比如倾斜的地形和不均匀的地面反照率。在这项工作中，我们描述了ANTS-2D，一种新的，计算效率高的二维视图因子模型，用于计算模块表面的前后侧辐照度，同时考虑了地面反照率和倾斜地形的不均匀性。对于水平和均匀地面的基本情况，我们表明该模型相对于光线追踪模型基线的精度在最佳可用替代视图因子模型的大约1 W m$^{-2}$范围内，同时还具有计算时间减少85%的特点。该模型还允许详细的地面辐照度，对农业发电应用特别有用。
{"title":"A Bifacial View Factor Model Considering Terrain Slope and Nonuniform Albedo","authors":"Kevin S. Anderson;Adam R. Jensen;Clifford W. Hansen","doi":"10.1109/JPHOTOV.2026.3677506","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2026.3677506","url":null,"abstract":"Simulation models used to develop and finance bifacial photovoltaic systems estimate rear-side irradiance using 2-D view factor models. These models make simplifying assumptions that do not account for complexities—such as sloped terrain and nonuniform ground albedo—found in modern photovoltaic systems. In this work, we describe ANTS-2D, a new, computationally efficient 2-D view factor model for computing front- and rear-side irradiance across the module surface, considering both nonuniformity in ground albedo and sloped terrain. For the base case of a horizontal and uniform ground surface, we show that the model's accuracy relative to a ray-tracing model baseline is within approximately 1 W m<inline-formula><tex-math>$^{-2}$</tex-math></inline-formula> of the best available alternative view factor model while also featuring an 85% reduction in computation time. The model also allows for detailed ground irradiances, particularly useful for agrivoltaic applications.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"16 4","pages":"605-613"},"PeriodicalIF":3.7,"publicationDate":"2026-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://ieeexplore.ieee.org/stamp/stamp.jsp?tp=&arnumber=11477090","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148443223","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Partial shading significantly affects the performance and efficiency of photovoltaic (PV) arrays, leading to mismatch losses (MLs) and reduced energy output. This research proposes a novel odd-even column major order reconfiguration strategy to mitigate these challenges and optimize the performance of the total-cross-tied (TCT) PV array. The proposed method focuses on redistributing the shade by rearranging the PV modules while preserving TCT electrical connections, minimizing MLs, and enhancing the power generation. The proposed strategy is evaluated through extensive simulations and experimental validation on a 6 × 6 PV array under various shading scenarios using key performance indices such as global maximum power point, ML, power enhancement (PE), fill factor, and efficiency. Results demonstrate a significant improvement across all indices, with up to 19.86% PE, ML reduction to 1.46%, and a maximum efficiency of 16.96%. Therefore, the proposed method presents an effective solution to shading-induced challenges in PV arrays, promoting sustainable energy generation and advancing the adoption of solar power in diverse environmental conditions.
{"title":"An Odd-Even Column Major Order Approach for Optimal Shade Dispersion Over the Solar PV Arrays","authors":"B.S.S. Santosh;Gadiraju Harish Kumar Varma;Diwaker Pathak;Gourav Verma;Venugopal Reddy Barry;Sanjeevikumar Padmanaban","doi":"10.1109/JPHOTOV.2026.3661113","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2026.3661113","url":null,"abstract":"Partial shading significantly affects the performance and efficiency of photovoltaic (PV) arrays, leading to mismatch losses (MLs) and reduced energy output. This research proposes a novel odd-even column major order reconfiguration strategy to mitigate these challenges and optimize the performance of the total-cross-tied (TCT) PV array. The proposed method focuses on redistributing the shade by rearranging the PV modules while preserving TCT electrical connections, minimizing MLs, and enhancing the power generation. The proposed strategy is evaluated through extensive simulations and experimental validation on a 6 × 6 PV array under various shading scenarios using key performance indices such as global maximum power point, ML, power enhancement (PE), fill factor, and efficiency. Results demonstrate a significant improvement across all indices, with up to 19.86% PE, ML reduction to 1.46%, and a maximum efficiency of 16.96%. Therefore, the proposed method presents an effective solution to shading-induced challenges in PV arrays, promoting sustainable energy generation and advancing the adoption of solar power in diverse environmental conditions.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"16 4","pages":"465-474"},"PeriodicalIF":3.7,"publicationDate":"2026-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://ieeexplore.ieee.org/stamp/stamp.jsp?tp=&arnumber=11396668","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148517309","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-07-01Epub Date: 2026-03-12DOI: 10.1109/JPHOTOV.2026.3667920
Janne Lauri;Dara Moazami Goodarzi;Tapio Fabritius
In photovoltaic modules, individual cells are interconnected with metal ribbons that are typically copper wires coated with soldering alloy. Due to different thermal expansion coefficients of copper and silicon as well as residual stress and cracks originating from a soldering process, thermal fatigue can appear after years of usage in the field and will lead to severe cracks and poor electrical connection between the cells. We have demonstrated eddy current soldering as a method to solder solar cell’s interconnections through a glass. The method was proposed to repair and refurbish bad electrical connections encapsulated underneath a glass layer. The glass encapsulant hampers the monitoring of actual temperatures in the soldering area, and therefore, only the glass surface temperature was used for monitoring process temperature. Soldering temperature and time will have an influence on soldering contact properties, morphology, and reliability. Thus, it is important to know absolute temperatures within the soldering zone. In this work, we simulate the eddy current soldering process under layer of glass to evaluate temperatures within the ribbon and the solar cell during the soldering process. The simulation results are verified with the data obtained from the experiments.
{"title":"Modeling of Eddy Current Soldering and Temperature Distributions in Solar Cell Tabbing Process Under Layer of Glass","authors":"Janne Lauri;Dara Moazami Goodarzi;Tapio Fabritius","doi":"10.1109/JPHOTOV.2026.3667920","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2026.3667920","url":null,"abstract":"In photovoltaic modules, individual cells are interconnected with metal ribbons that are typically copper wires coated with soldering alloy. Due to different thermal expansion coefficients of copper and silicon as well as residual stress and cracks originating from a soldering process, thermal fatigue can appear after years of usage in the field and will lead to severe cracks and poor electrical connection between the cells. We have demonstrated eddy current soldering as a method to solder solar cell’s interconnections through a glass. The method was proposed to repair and refurbish bad electrical connections encapsulated underneath a glass layer. The glass encapsulant hampers the monitoring of actual temperatures in the soldering area, and therefore, only the glass surface temperature was used for monitoring process temperature. Soldering temperature and time will have an influence on soldering contact properties, morphology, and reliability. Thus, it is important to know absolute temperatures within the soldering zone. In this work, we simulate the eddy current soldering process under layer of glass to evaluate temperatures within the ribbon and the solar cell during the soldering process. The simulation results are verified with the data obtained from the experiments.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"16 4","pages":"399-407"},"PeriodicalIF":3.7,"publicationDate":"2026-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://ieeexplore.ieee.org/stamp/stamp.jsp?tp=&arnumber=11432958","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148518733","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-07-01Epub Date: 2026-02-26DOI: 10.1109/JPHOTOV.2026.3665331
Derick Mathew;J. Prasanth Ram;Young-Jin Kim
Microinverter-based photovoltaic (PV) systems face reliability risks under partial shading, where bypass diode activation causes shaded submodules (SMs) to dissipate power, creating hotspots and accelerating degradation. Conventional active power tracking (APT) methods often operate in these hotspot-prone zones, resulting in shaded-cell heating, power oscillations when Pref>PMPP, and microinverter restarts. This article proposes a safe zone operation–enforced APT algorithm that enhances the conventional method to ensure oscillation-free regulation while preventing reverse bias stress in shaded SMs. The algorithm dynamically identifies operating regions, halts perturbations under Pref>PMPP, and integrates a minimum power threshold concept to avoid collapse to an open circuit during irradiance drops. Experimental validation on a microinverter prototype, supported by thermal simulations, demonstrates complete elimination of shaded SM dissipation, stable tracking across irradiance and reference variations, and continuous operation without restart. Compared to existing methods, the proposed strategy prioritizes long-term reliability while maintaining tracking accuracy, establishing a safety-driven benchmark for microinverter PV systems.
{"title":"Safe-Zone Enforced Power Tracking for Hotspot Mitigation in Shaded Microinverter PV Systems","authors":"Derick Mathew;J. Prasanth Ram;Young-Jin Kim","doi":"10.1109/JPHOTOV.2026.3665331","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2026.3665331","url":null,"abstract":"Microinverter-based photovoltaic (PV) systems face reliability risks under partial shading, where bypass diode activation causes shaded submodules (SMs) to dissipate power, creating hotspots and accelerating degradation. Conventional active power tracking (APT) methods often operate in these hotspot-prone zones, resulting in shaded-cell heating, power oscillations when <italic>P</i><sub>ref</sub>><italic>P</i><sub>MPP</sub>, and microinverter restarts. This article proposes a safe zone operation–enforced APT algorithm that enhances the conventional method to ensure oscillation-free regulation while preventing reverse bias stress in shaded SMs. The algorithm dynamically identifies operating regions, halts perturbations under <italic>P</i><sub>ref</sub>><italic>P</i><sub>MPP</sub>, and integrates a minimum power threshold concept to avoid collapse to an open circuit during irradiance drops. Experimental validation on a microinverter prototype, supported by thermal simulations, demonstrates complete elimination of shaded SM dissipation, stable tracking across irradiance and reference variations, and continuous operation without restart. Compared to existing methods, the proposed strategy prioritizes long-term reliability while maintaining tracking accuracy, establishing a safety-driven benchmark for microinverter PV systems.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"16 4","pages":"552-561"},"PeriodicalIF":3.7,"publicationDate":"2026-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148519017","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Bifacial solar modules have gained increasing popularity due to their enhanced mechanical strength, corrosion resistance, and ability to capture light from both the front and rear sides, offering improved performance compared to traditional encapsulation methods. However, to fully understand the degradation mechanisms in aged bifacial modules, microscopic analysis is required, which typically involves removing the encapsulation layers without compromising the underlying solar cells. In this study, we present a damage-free coring technique for bifacial solar modules. This method involves bonding a regular glass layer as a protective shield, preventing damage from shattered tempered glass during the coring process. This approach enables the safe removal of encapsulation layers and the precise extraction of localized solar cells for subsequent microscopic analysis, without introducing new defects. Through a combination of macroscopic and microscopic characterization, we demonstrate that the extracted cells remain intact, functional, and free from degradation induced by the coring process. This technique offers a simple, efficient, and cost-effective solution for in-depth analysis of aged bifacial modules, facilitating improved understanding of their long-term performance and degradation mechanisms.
{"title":"Damage-Free Coring Technique for Bifacial Glass–Glass Silicon Solar Modules","authors":"Yangyang Gou;Junchuan Zhang;Xirui Liu;Minghui Li;Yongjie Jiang;Xiting Lang;Jing Qiu;Yujian Han;Jichun Ye;Chuanxiao Xiao","doi":"10.1109/JPHOTOV.2026.3665363","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2026.3665363","url":null,"abstract":"Bifacial solar modules have gained increasing popularity due to their enhanced mechanical strength, corrosion resistance, and ability to capture light from both the front and rear sides, offering improved performance compared to traditional encapsulation methods. However, to fully understand the degradation mechanisms in aged bifacial modules, microscopic analysis is required, which typically involves removing the encapsulation layers without compromising the underlying solar cells. In this study, we present a damage-free coring technique for bifacial solar modules. This method involves bonding a regular glass layer as a protective shield, preventing damage from shattered tempered glass during the coring process. This approach enables the safe removal of encapsulation layers and the precise extraction of localized solar cells for subsequent microscopic analysis, without introducing new defects. Through a combination of macroscopic and microscopic characterization, we demonstrate that the extracted cells remain intact, functional, and free from degradation induced by the coring process. This technique offers a simple, efficient, and cost-effective solution for in-depth analysis of aged bifacial modules, facilitating improved understanding of their long-term performance and degradation mechanisms.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"16 4","pages":"475-482"},"PeriodicalIF":3.7,"publicationDate":"2026-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148519011","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-07-01Epub Date: 2026-03-14DOI: 10.1109/JPHOTOV.2026.3687907
Breno Bezerra Freitas;Paulo Cesar Marques de Carvalho;José Carlos de Araújo;Leticia de Oliveira Santos
Floating photovoltaic (FPV) systems have gained attention worldwide due to their potential gains in generation, land saving, and water evaporation reduction. However, experimental data from installed FPV plants operating under high irradiance and ambient temperature remains scarce. Our study presents an experimental assessment comparing FPV and ground-mounted photovoltaic (GPV) systems installed side by side in an urban area under semiarid climate. The analysis considers operating weather conditions, and focuses on photovoltaic (PV) modules’ thermal and electrical behavior, as well as on the impact of FPV on the water evaporation rates. The FPV system covers 50% of the surface of a water tank; an adjacent uncovered tank is used as a reference for evaporation data. Overall, FPV and GPV modules show a similar electrical performance, with equivalence tests indicating that differences remain practically negligible at the operational scale (between $-$1.08% and 0.06%). FPV modules often operate at similar or slightly higher temperatures than GPV modules, consequence of low wind speed values, usually found in urban environments. In contrast, FPV modules consistently reduce water evaporation, with an average reduction of 40%, saving about 8.4 m$^{3}$ during the period.
{"title":"Floating Photovoltaic Systems in Urban Areas: Insights on the Thermoelectric Behavior and Water Evaporation Reduction","authors":"Breno Bezerra Freitas;Paulo Cesar Marques de Carvalho;José Carlos de Araújo;Leticia de Oliveira Santos","doi":"10.1109/JPHOTOV.2026.3687907","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2026.3687907","url":null,"abstract":"Floating photovoltaic (FPV) systems have gained attention worldwide due to their potential gains in generation, land saving, and water evaporation reduction. However, experimental data from installed FPV plants operating under high irradiance and ambient temperature remains scarce. Our study presents an experimental assessment comparing FPV and ground-mounted photovoltaic (GPV) systems installed side by side in an urban area under semiarid climate. The analysis considers operating weather conditions, and focuses on photovoltaic (PV) modules’ thermal and electrical behavior, as well as on the impact of FPV on the water evaporation rates. The FPV system covers 50% of the surface of a water tank; an adjacent uncovered tank is used as a reference for evaporation data. Overall, FPV and GPV modules show a similar electrical performance, with equivalence tests indicating that differences remain practically negligible at the operational scale (between <inline-formula><tex-math>$-$</tex-math></inline-formula>1.08% and 0.06%). FPV modules often operate at similar or slightly higher temperatures than GPV modules, consequence of low wind speed values, usually found in urban environments. In contrast, FPV modules consistently reduce water evaporation, with an average reduction of 40%, saving about 8.4 m<inline-formula><tex-math>$^{3}$</tex-math></inline-formula> during the period.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"16 4","pages":"614-622"},"PeriodicalIF":3.7,"publicationDate":"2026-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://ieeexplore.ieee.org/stamp/stamp.jsp?tp=&arnumber=11520340","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148442891","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
This research article proposes a distributed maximum power point tracking (MPPT) strategy in a dual-faced open cubic photovoltaic (DFOC-PV) system using K-means clustering. The system is designed to harvest solar energy continuously throughout the day, independent of the sun's direction, thereby eliminating the need for mechanical tracking mechanisms. Due to its compact and direction-free design, the proposed architecture is highly suitable for space-constrained environments. In contrast, conventional flat-panel PV systems are limited by large area requirements for comparable power output. This work comprehensively investigates all feasible array configurations of the DFOC-PV system under natural partial shading, which inherently occurs due to its structural design. The results indicate that the integration of a distributed maximum power extraction (DMPE) circuit significantly improves the energy yield across all configurations. The hardware experiments demonstrate that, for an identical land area, the proposed DFOC-PV system delivers higher energy output than a conventional flat-panel PV system under sunny, partly cloudy, and cloudy conditions. To further enhance performance under nonuniform irradiance conditions, the 28 PV panels in the proposed DFOC-PV system are grouped using K-means clustering algorithm, based on irradiance similarity. Clustering reduces current mismatch losses and improves overall energy harvesting by up to 2.1% under partial shading. Finally, a techno-economic analysis confirms the feasibility of the proposed system, yielding a lower levelized cost of energy ($unicode{x20B9}$13.28/kWh), a higher internal rate of return (14%), and a decreased energy payback period compared to the conventional PV configuration.
{"title":"Distributed MPPT in Dual-Faced Open Cubic PV System Using K-Means Clustering","authors":"Ajay Kumar Prajapat;Sishaj P Simon;P Srinivasa Rao Nayak;K Sundareswaran;Narayana Prasad Padhy","doi":"10.1109/JPHOTOV.2026.3673773","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2026.3673773","url":null,"abstract":"This research article proposes a distributed maximum power point tracking (MPPT) strategy in a dual-faced open cubic photovoltaic (DFOC-PV) system using K-means clustering. The system is designed to harvest solar energy continuously throughout the day, independent of the sun's direction, thereby eliminating the need for mechanical tracking mechanisms. Due to its compact and direction-free design, the proposed architecture is highly suitable for space-constrained environments. In contrast, conventional flat-panel PV systems are limited by large area requirements for comparable power output. This work comprehensively investigates all feasible array configurations of the DFOC-PV system under natural partial shading, which inherently occurs due to its structural design. The results indicate that the integration of a distributed maximum power extraction (DMPE) circuit significantly improves the energy yield across all configurations. The hardware experiments demonstrate that, for an identical land area, the proposed DFOC-PV system delivers higher energy output than a conventional flat-panel PV system under sunny, partly cloudy, and cloudy conditions. To further enhance performance under nonuniform irradiance conditions, the 28 PV panels in the proposed DFOC-PV system are grouped using K-means clustering algorithm, based on irradiance similarity. Clustering reduces current mismatch losses and improves overall energy harvesting by up to 2.1% under partial shading. Finally, a techno-economic analysis confirms the feasibility of the proposed system, yielding a lower levelized cost of energy (<inline-formula><tex-math>$unicode{x20B9}$</tex-math></inline-formula>13.28/kWh), a higher internal rate of return (14%), and a decreased energy payback period compared to the conventional PV configuration.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"16 4","pages":"562-571"},"PeriodicalIF":3.7,"publicationDate":"2026-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148519018","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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