Pub Date : 2025-03-28DOI: 10.1109/JPHOTOV.2025.3551505
Amr Osama;Giuseppe Marco Tina;Gaetano Mannino;Alessio Vincenzo Cucuzza;Andrea Canino;Fabrizio Bizzarri
The rapid expansion of photovoltaics is driven by significant reduction in costs. However, given the surface requirements for photovoltaic development, utilizing water surfaces for floating photovoltaic (FPV) systems presents a promising solution. To enhance the cost-effectiveness of these systems, bifacial modules and tracking systems can be employed. While numerous experimental studies have evaluated the performance of fixed-configuration FPVs, floating tracking configurations remain underexplored. In addition, various simulation tools offer insights into different configurations, but their different assumptions often yield inconsistent results. This study focuses on the experimental evaluation of a horizontal axis tracking bifacial FPV (HT-bFPV) system. Over one year, the HT-bFPV system was monitored at the FPV test bed of “Enel Innovation Hub & Lab” in Catania, Italy. The experimental results were compared with simulated outcomes using two software tools, to assess their precision in calculating the HT-bFPV performances. The results reveal that the module temperature of the HT-bFPV system is 3 °C to 6 °C lower than the temperatures calculated by System Advisor Model and Photovoltaic system software, respectively. The yearly reference yield of 2139 kWh/kW produced a final yield of 1801 kWh/kW. The yearly performance ratio of the HT-bFPV system was 0.86, which improved by 1.8% when adjusted for temperature. The simulation results closely matched the experimental data, validating the system's performance. Furthermore, it was confirmed that the HT-bFPV system can produce up to 13.3% more energy with more potential in sites with higher latitudes compared with a similar fixed system.
{"title":"Experimental and Simulated Performance Evaluation of Bifacial Photovoltaic Floating System With a Horizontal Single-Axial Tracker","authors":"Amr Osama;Giuseppe Marco Tina;Gaetano Mannino;Alessio Vincenzo Cucuzza;Andrea Canino;Fabrizio Bizzarri","doi":"10.1109/JPHOTOV.2025.3551505","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3551505","url":null,"abstract":"The rapid expansion of photovoltaics is driven by significant reduction in costs. However, given the surface requirements for photovoltaic development, utilizing water surfaces for floating photovoltaic (FPV) systems presents a promising solution. To enhance the cost-effectiveness of these systems, bifacial modules and tracking systems can be employed. While numerous experimental studies have evaluated the performance of fixed-configuration FPVs, floating tracking configurations remain underexplored. In addition, various simulation tools offer insights into different configurations, but their different assumptions often yield inconsistent results. This study focuses on the experimental evaluation of a horizontal axis tracking bifacial FPV (HT-bFPV) system. Over one year, the HT-bFPV system was monitored at the FPV test bed of “Enel Innovation Hub & Lab” in Catania, Italy. The experimental results were compared with simulated outcomes using two software tools, to assess their precision in calculating the HT-bFPV performances. The results reveal that the module temperature of the HT-bFPV system is 3 °C to 6 °C lower than the temperatures calculated by System Advisor Model and Photovoltaic system software, respectively. The yearly reference yield of 2139 kWh/kW produced a final yield of 1801 kWh/kW. The yearly performance ratio of the HT-bFPV system was 0.86, which improved by 1.8% when adjusted for temperature. The simulation results closely matched the experimental data, validating the system's performance. Furthermore, it was confirmed that the HT-bFPV system can produce up to 13.3% more energy with more potential in sites with higher latitudes compared with a similar fixed system.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 3","pages":"484-491"},"PeriodicalIF":2.5,"publicationDate":"2025-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143860995","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 : 2025-03-26DOI: 10.1109/JPHOTOV.2025.3547046
Elisa Kaiser;Maike Wiesenfarth;Marc Steiner;Gerald Siefer;Peter Nitz;Peter Schöttl;Stefan W. Glunz;Henning Helmers
Micro-concentrating photovoltaic (micro-CPV) technology has the potential to contribute to the energy transition, facilitating the shift toward more sustainable and renewable energy sources by combining minimal carbon footprint and energy demand with low levelized cost of electricity. Micro-CPV modules utilize direct normal irradiance to convert sunlight into electrical power, necessitating precise solar tracking. The performance of these modules is influenced by their alignment toward the sun and prevailing outdoor conditions during outdoor operation. The spectral conditions, along with the ambient temperature, irradiance, and wind speed, influence the current–voltage characteristics of multijunction solar cells and the optical behavior of the lens. We have developed a novel micro-CPV module concept, which is based on low-cost and high-throughput manufacturing processes. In this work, we present a prototype module in a 10 × 6 array configuration (205-cm2 aperture area, submodule class). We discuss outdoor measurements recorded over one year and the influences of various outdoor conditions. In an IEC62670-3 power rating, efficiencies of 36.0 ± 0.4% and 33.0 ± 0.4% at concentrator standard test conditions and concentrator standard operating conditions, respectively, are determined. Highest efficiencies, about 0.4% higher than at standard conditions, were attained at a more red-rich spectrum, namely at a spectral matching ratio SMR12 of 0.94 ± 0.03. Using measurements at different temperatures, we show that the planoconvex silicone-on-glass primary lens has a negligible temperature dependence. Changes in the module performance over the course of one year are discussed. Despite employing commercially available low-cost components and high-throughput processes, no significant degradation was observed during the first year of operation.
{"title":"Power Rating of a Novel Micro-CPV Module Concept and Operational Influences","authors":"Elisa Kaiser;Maike Wiesenfarth;Marc Steiner;Gerald Siefer;Peter Nitz;Peter Schöttl;Stefan W. Glunz;Henning Helmers","doi":"10.1109/JPHOTOV.2025.3547046","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3547046","url":null,"abstract":"Micro-concentrating photovoltaic (micro-CPV) technology has the potential to contribute to the energy transition, facilitating the shift toward more sustainable and renewable energy sources by combining minimal carbon footprint and energy demand with low levelized cost of electricity. Micro-CPV modules utilize direct normal irradiance to convert sunlight into electrical power, necessitating precise solar tracking. The performance of these modules is influenced by their alignment toward the sun and prevailing outdoor conditions during outdoor operation. The spectral conditions, along with the ambient temperature, irradiance, and wind speed, influence the current–voltage characteristics of multijunction solar cells and the optical behavior of the lens. We have developed a novel micro-CPV module concept, which is based on low-cost and high-throughput manufacturing processes. In this work, we present a prototype module in a 10 × 6 array configuration (205-cm<sup>2</sup> aperture area, submodule class). We discuss outdoor measurements recorded over one year and the influences of various outdoor conditions. In an IEC62670-3 power rating, efficiencies of 36.0 ± 0.4% and 33.0 ± 0.4% at concentrator standard test conditions and concentrator standard operating conditions, respectively, are determined. Highest efficiencies, about 0.4% higher than at standard conditions, were attained at a more red-rich spectrum, namely at a spectral matching ratio <italic>SMR</i><sub>12</sub> of 0.94 ± 0.03. Using measurements at different temperatures, we show that the planoconvex silicone-on-glass primary lens has a negligible temperature dependence. Changes in the module performance over the course of one year are discussed. Despite employing commercially available low-cost components and high-throughput processes, no significant degradation was observed during the first year of operation.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 3","pages":"434-441"},"PeriodicalIF":2.5,"publicationDate":"2025-03-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://ieeexplore.ieee.org/stamp/stamp.jsp?tp=&arnumber=10938951","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143860921","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}
Floating photovoltaic (FPV) systems are emerging as a promising solution to the scarcity of suitable land for ground-mounted solar PV (GPV) installations. By the end of 2022, global FPV capacity reached 5.7 GWp following a remarkable compound annual growth rate of approximately 87.5% from 2015 to 2022. This growth introduces a significant new frontier for operation and maintenance (O&M) practices in the solar industry. As the industry matures and more FPV assets come under operation, the need for innovative, efficient, and environmentally sensitive O&M strategies becomes imperative. This review presents the existing information on the O&M of FPV systems, highlighting the unique challenges and opportunities that set FPV systems apart from conventional GPV installations. Through an examination of recent advancements, best practices, and areas requiring further research, this study aims to provide valuable insights for optimizing the performance and sustainability of FPV systems.
{"title":"Operation and Maintenance of Floating PV Systems: A Review","authors":"Harsha Lakmal Walpita;Nathan Roosloot;Gaute Otnes;Bjørn Lupton Aarseth;Josefine Selj;Vilde Stueland Nysted;Erik Stensrud Marstein","doi":"10.1109/JPHOTOV.2025.3548322","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3548322","url":null,"abstract":"Floating photovoltaic (FPV) systems are emerging as a promising solution to the scarcity of suitable land for ground-mounted solar PV (GPV) installations. By the end of 2022, global FPV capacity reached 5.7 GWp following a remarkable compound annual growth rate of approximately 87.5% from 2015 to 2022. This growth introduces a significant new frontier for operation and maintenance (O&M) practices in the solar industry. As the industry matures and more FPV assets come under operation, the need for innovative, efficient, and environmentally sensitive O&M strategies becomes imperative. This review presents the existing information on the O&M of FPV systems, highlighting the unique challenges and opportunities that set FPV systems apart from conventional GPV installations. Through an examination of recent advancements, best practices, and areas requiring further research, this study aims to provide valuable insights for optimizing the performance and sustainability of FPV systems.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 3","pages":"400-415"},"PeriodicalIF":2.5,"publicationDate":"2025-03-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143860829","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 : 2025-03-21DOI: 10.1109/JPHOTOV.2025.3548762
Nathan Roosloot;Dag Lindholm;Josefine H. Selj;Gaute Otnes
Floating photovoltaic (FPV) modules may face a risk of increased moisture ingress due to their deployment on water surfaces. One way to mitigate this is by using impermeable front- and backsheets, with an edge sealant around the module perimeter. While a suitable sealant should have low bulk permeability, proper sealant application to avoid higher ingress channels at interfaces is crucial. Here, we report on the use of a gravimetric method as a simple way of evaluating moisture ingress through an edge sealant and of identifying application-related issues that lead to increased moisture ingress. The method uses multiple samples that closely mimic the sealant's intended application as part of an FPV design developed by the company Sunlit Sea. Supported by steady-state water vapor transmission rate measurements and finite-element modeling, the method is shown to be capable of determining the order of magnitude of the permeability of two different candidate sealant materials. Moreover, the method detected several application-related sealant failures that were not discernible through visual inspection. Finally, it uncovered potential issues of debonding of one of the sealants in immersion, highlighting a relevant yet understudied stressor for FPV modules.
{"title":"Gravimetric Analysis of Edge Sealant Moisture Protection in a Floating Photovoltaic Application","authors":"Nathan Roosloot;Dag Lindholm;Josefine H. Selj;Gaute Otnes","doi":"10.1109/JPHOTOV.2025.3548762","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3548762","url":null,"abstract":"Floating photovoltaic (FPV) modules may face a risk of increased moisture ingress due to their deployment on water surfaces. One way to mitigate this is by using impermeable front- and backsheets, with an edge sealant around the module perimeter. While a suitable sealant should have low bulk permeability, proper sealant application to avoid higher ingress channels at interfaces is crucial. Here, we report on the use of a gravimetric method as a simple way of evaluating moisture ingress through an edge sealant and of identifying application-related issues that lead to increased moisture ingress. The method uses multiple samples that closely mimic the sealant's intended application as part of an FPV design developed by the company Sunlit Sea. Supported by steady-state water vapor transmission rate measurements and finite-element modeling, the method is shown to be capable of determining the order of magnitude of the permeability of two different candidate sealant materials. Moreover, the method detected several application-related sealant failures that were not discernible through visual inspection. Finally, it uncovered potential issues of debonding of one of the sealants in immersion, highlighting a relevant yet understudied stressor for FPV modules.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 3","pages":"442-450"},"PeriodicalIF":2.5,"publicationDate":"2025-03-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143860812","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 : 2025-03-18DOI: 10.1109/JPHOTOV.2025.3546318
Ali Baghban Parashkouh;Ali Sadr;Maryam Heidariramsheh;Nima Taghavinia
Physical and chemical controlling of the lead halide perovskite films is crucial to minimize defects and improve overall performance and stability of perovskite solar cells. In this study, applying a hot flow of dry air on the surface of perovskite films during hot plate annealing is investigated. We found that this technique leads to a smooth texture and reduces the surface defects. A hot dry airflow of 15 L/min improves the power conversion efficiency from 13.56% to 15.31%, with approximately 4.3% and 10.4% enhancement of fill factor and short-circuit current density, respectively. However, increasing the rate of dry airflow leads to large voids, which is a critical concern for leakage current and performance degradation.
{"title":"Improved Lead Halide Perovskite Films and Devices Using Hot-Flow-Assisted Annealing","authors":"Ali Baghban Parashkouh;Ali Sadr;Maryam Heidariramsheh;Nima Taghavinia","doi":"10.1109/JPHOTOV.2025.3546318","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3546318","url":null,"abstract":"Physical and chemical controlling of the lead halide perovskite films is crucial to minimize defects and improve overall performance and stability of perovskite solar cells. In this study, applying a hot flow of dry air on the surface of perovskite films during hot plate annealing is investigated. We found that this technique leads to a smooth texture and reduces the surface defects. A hot dry airflow of 15 L/min improves the power conversion efficiency from 13.56% to 15.31%, with approximately 4.3% and 10.4% enhancement of fill factor and short-circuit current density, respectively. However, increasing the rate of dry airflow leads to large voids, which is a critical concern for leakage current and performance degradation.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 3","pages":"427-433"},"PeriodicalIF":2.5,"publicationDate":"2025-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143860856","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 : 2025-03-14DOI: 10.1109/JPHOTOV.2025.3542830
Nick Bosco
The What's Cracking app can predict how changes in crystalline silicon photovoltaic (PV) module materials, design, and mounting affect its susceptibility for cell fracture under uniform loading. This work has experimentally validated the app. A set of commercial crystalline silicon PV modules was obtained for this study. The modules were uniformly loaded at three different mounting points, and their subsequent cell fractures were recorded. A large sample size allowed for the development of an experimental statistical model for cell fracture. The comparison of the experiment to predictions from the app is in excellent agreement. Both experimental and modeling results also elucidate how moving the module mounting points toward the center of the module increases the probability of cell fracture.
{"title":"Experimental Validation of a Module Cell Cracking Model","authors":"Nick Bosco","doi":"10.1109/JPHOTOV.2025.3542830","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3542830","url":null,"abstract":"The What's Cracking app can predict how changes in crystalline silicon photovoltaic (PV) module materials, design, and mounting affect its susceptibility for cell fracture under uniform loading. This work has experimentally validated the app. A set of commercial crystalline silicon PV modules was obtained for this study. The modules were uniformly loaded at three different mounting points, and their subsequent cell fractures were recorded. A large sample size allowed for the development of an experimental statistical model for cell fracture. The comparison of the experiment to predictions from the app is in excellent agreement. Both experimental and modeling results also elucidate how moving the module mounting points toward the center of the module increases the probability of cell fracture.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 3","pages":"416-419"},"PeriodicalIF":2.5,"publicationDate":"2025-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143860918","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 : 2025-03-13DOI: 10.1109/JPHOTOV.2025.3545825
Dylan J. Colvin;Andrew M. Gabor;William C. Oltjen;Philip J. Knodle;Ange Dominique Yao;Brent A. Thompson;Nadia Khan;Sina Lotfian;Joseph Raby;Albert Jojo;Xuanji Yu;Max Liggett;Hubert P. Seigneur;Roger H. French;Laura S. Bruckman;Mengjie Li;Kristopher O. Davis
As the photovoltaics (PV) industry grows in sophistication, so must the extent to which systems are characterized. UV Fluorescence (UVF) imaging is a valuable, easy-to-perform, high-throughput, nonintrusive technique for characterizing modules in the field and in the lab. However, UVF is still a relatively new technique, and many in the PV industry are still unaware of its potential. We provide a guideline for obtaining, processing, and interpreting UVF images. We have provided a list of considerations for imaging hardware and settings, a suggested pipeline for image processing, and details on a survey of features shown in UVF images. A new database with UVF images of 7190 modules and another database curated by BrightSpot Automation are publicly available.
{"title":"Ultraviolet Fluorescence Imaging for Photovoltaic Module Metrology: Best Practices and Survey of Features Observed in Fielded Modules","authors":"Dylan J. Colvin;Andrew M. Gabor;William C. Oltjen;Philip J. Knodle;Ange Dominique Yao;Brent A. Thompson;Nadia Khan;Sina Lotfian;Joseph Raby;Albert Jojo;Xuanji Yu;Max Liggett;Hubert P. Seigneur;Roger H. French;Laura S. Bruckman;Mengjie Li;Kristopher O. Davis","doi":"10.1109/JPHOTOV.2025.3545825","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3545825","url":null,"abstract":"As the photovoltaics (PV) industry grows in sophistication, so must the extent to which systems are characterized. UV Fluorescence (UVF) imaging is a valuable, easy-to-perform, high-throughput, nonintrusive technique for characterizing modules in the field and in the lab. However, UVF is still a relatively new technique, and many in the PV industry are still unaware of its potential. We provide a guideline for obtaining, processing, and interpreting UVF images. We have provided a list of considerations for imaging hardware and settings, a suggested pipeline for image processing, and details on a survey of features shown in UVF images. A new database with UVF images of 7190 modules and another database curated by BrightSpot Automation are publicly available.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 3","pages":"465-477"},"PeriodicalIF":2.5,"publicationDate":"2025-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143860916","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 : 2025-03-13DOI: 10.1109/JPHOTOV.2025.3545820
Rajiv Daxini;Kevin S. Anderson;Joshua S. Stein;Marios Theristis
Understanding the impact of variation in the solar spectrum on photovoltaic (PV) device output is critical for accurate and reliable PV performance modeling. While previous studies have examined these spectral effects extensively at the module level, this study examines the spectral impact at the cell level and how subsequent current mismatch can influence module-level output. Cell-level external quantum efficiency (EQE) data from 11 new commercial PV modules are analyzed. The module power output, as determined by the spectral mismatch factor of the module-limiting cell, is computed using the measured cell EQE data in conjunction with gridded meteorological and spectral irradiance data simulated at an approximately 20 $mathbf{mathrm{km}}$ resolution across the contiguous USA over one year. This study finds only a small variation in annualized module output of around 0.2% as a result of intramodule EQE variation. However, these losses exhibit significant seasonality, varying by up to around four times the annualized energy difference on a month-to-month basis. The seasonality of the energy loss has implications for subannual PV performance analysis applications such as capacity testing.
{"title":"Photovoltaic Module Spectral Mismatch Losses Due to Cell-Level EQE Variation","authors":"Rajiv Daxini;Kevin S. Anderson;Joshua S. Stein;Marios Theristis","doi":"10.1109/JPHOTOV.2025.3545820","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3545820","url":null,"abstract":"Understanding the impact of variation in the solar spectrum on photovoltaic (PV) device output is critical for accurate and reliable PV performance modeling. While previous studies have examined these spectral effects extensively at the module level, this study examines the spectral impact at the cell level and how subsequent current mismatch can influence module-level output. Cell-level external quantum efficiency (EQE) data from 11 new commercial PV modules are analyzed. The module power output, as determined by the spectral mismatch factor of the module-limiting cell, is computed using the measured cell EQE data in conjunction with gridded meteorological and spectral irradiance data simulated at an approximately 20 <inline-formula><tex-math>$mathbf{mathrm{km}}$</tex-math></inline-formula> resolution across the contiguous USA over one year. This study finds only a small variation in annualized module output of around 0.2% as a result of intramodule EQE variation. However, these losses exhibit significant seasonality, varying by up to around four times the annualized energy difference on a month-to-month basis. The seasonality of the energy loss has implications for subannual PV performance analysis applications such as capacity testing.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 3","pages":"458-464"},"PeriodicalIF":2.5,"publicationDate":"2025-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://ieeexplore.ieee.org/stamp/stamp.jsp?tp=&arnumber=10925465","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143860937","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}
Methods for fully characterizing the harmonic injection amount of distributed photovoltaic grid connection and combining harmonic constraints with other constraints to accurately evaluate the hosting capacity of photovoltaic integration into distribution networks are of great significance as they ensure the safe and stable operation of distribution networks. Therefore, a novel hosting capacity evaluation method for distributed photovoltaics (PVs) connected in a power system based on the maximum likelihood estimation of harmonics (MLE) is proposed in this study. First, using the likelihood function from the MLE method, the harmonic parameters of distributed photovoltaic injections are optimally estimated, allowing for the accurate assessment of harmonic outputs during photovoltaic grid connections. Furthermore, a harmonic partitioning method is devised; it characterizes the connection degree between nodes in the grid-connected system, and it divides the distribution network into regions. The scenario number in the estimation of hosting capacities is effectively reduced. Finally, a comparison is carried out relative to the conventional hosting capacity. The assessment method proposed in this study considers the harmonic access in the actual distributed PV grid-connected system. An improved harmonic partitioning method is established based on the harmonic injection amount. The evaluation of PV hosting capacities in the region ensures accuracy and reduces calculation times. They provide references for the access capacity of the distribution network.
{"title":"A Novel Hosting Capacity Evaluation Method for Distributed PV Connected in Power System Based on Maximum Likelihood Estimation of Harmonic","authors":"Hongtao Shi;Jiahao Zhu;Yuchao Li;Zhenyang Yan;Tingting Chen;Bai Zhang","doi":"10.1109/JPHOTOV.2025.3541402","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3541402","url":null,"abstract":"Methods for fully characterizing the harmonic injection amount of distributed photovoltaic grid connection and combining harmonic constraints with other constraints to accurately evaluate the hosting capacity of photovoltaic integration into distribution networks are of great significance as they ensure the safe and stable operation of distribution networks. Therefore, a novel hosting capacity evaluation method for distributed photovoltaics (PVs) connected in a power system based on the maximum likelihood estimation of harmonics (MLE) is proposed in this study. First, using the likelihood function from the MLE method, the harmonic parameters of distributed photovoltaic injections are optimally estimated, allowing for the accurate assessment of harmonic outputs during photovoltaic grid connections. Furthermore, a harmonic partitioning method is devised; it characterizes the connection degree between nodes in the grid-connected system, and it divides the distribution network into regions. The scenario number in the estimation of hosting capacities is effectively reduced. Finally, a comparison is carried out relative to the conventional hosting capacity. The assessment method proposed in this study considers the harmonic access in the actual distributed PV grid-connected system. An improved harmonic partitioning method is established based on the harmonic injection amount. The evaluation of PV hosting capacities in the region ensures accuracy and reduces calculation times. They provide references for the access capacity of the distribution network.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 3","pages":"500-508"},"PeriodicalIF":2.5,"publicationDate":"2025-02-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143860922","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 : 2025-02-20DOI: 10.1109/JPHOTOV.2025.3540337
{"title":"Call for Papers for a Special Issue of IEEE Transactions on Electron Devices","authors":"","doi":"10.1109/JPHOTOV.2025.3540337","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3540337","url":null,"abstract":"","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 2","pages":"375-376"},"PeriodicalIF":2.5,"publicationDate":"2025-02-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://ieeexplore.ieee.org/stamp/stamp.jsp?tp=&arnumber=10897236","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143455168","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}
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