Pub Date : 2023-11-01DOI: 10.1109/JPHOTOV.2023.3309008
Wenchao Miao;Yanfang Luo;Fei Wang;Chaoqiang Jiang
Photovoltaic (PV) system has been widely used to reduce the consumption of fossil fuels and environmental pollution. The PV system is susceptible to line-to-ground (LG) and line-to-line (LL) faults due to equipment aging and insulation damage. The LG and LL faults will lead to malfunction and even catastrophic fire hazards in a PV system. Usually, there are protection devices. However, the operation of the maximum power point tracking controller and the effect of partial shading will lower the fault current to be unable to trigger the protection devices. Thus, it is difficult to detect and locate the faults accurately. It is necessary to study the characteristics of LG and LL faults for fault detection. This article determines the voltage characteristics of the LG and LL faults with the consideration of fault impedance and partial shading. The fault detection and location algorithm based on fault voltage behavior is established and developed on MATLAB. According to the simulation and experimental results, the proposed technique can detect and locate the LG and LL faults effectively despite the effects of fault impedance and partial shading in a PV system.
{"title":"Fault Detection and Location Algorithm by Voltage Characteristics for PV System","authors":"Wenchao Miao;Yanfang Luo;Fei Wang;Chaoqiang Jiang","doi":"10.1109/JPHOTOV.2023.3309008","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2023.3309008","url":null,"abstract":"Photovoltaic (PV) system has been widely used to reduce the consumption of fossil fuels and environmental pollution. The PV system is susceptible to line-to-ground (LG) and line-to-line (LL) faults due to equipment aging and insulation damage. The LG and LL faults will lead to malfunction and even catastrophic fire hazards in a PV system. Usually, there are protection devices. However, the operation of the maximum power point tracking controller and the effect of partial shading will lower the fault current to be unable to trigger the protection devices. Thus, it is difficult to detect and locate the faults accurately. It is necessary to study the characteristics of LG and LL faults for fault detection. This article determines the voltage characteristics of the LG and LL faults with the consideration of fault impedance and partial shading. The fault detection and location algorithm based on fault voltage behavior is established and developed on MATLAB. According to the simulation and experimental results, the proposed technique can detect and locate the LG and LL faults effectively despite the effects of fault impedance and partial shading in a PV system.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"13 6","pages":"968-978"},"PeriodicalIF":3.0,"publicationDate":"2023-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"71903002","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 : 2023-11-01DOI: 10.1109/JPHOTOV.2023.3306073
Qing Xiong, A. Gattozzi, Xianyong Feng, Charles E. Penney, Chen Zhang, S. Ji, S. Strank, R. Hebner
Photovoltaic systems provide electrical power with reduced emissions at competitive costs compared to legacy systems. A low or medium voltage dc distribution system is usually used for solar integration. In dc systems, parallel and series arc faults are a safety concern. Thus, reliable and timely detection and mitigation of arc faults are critical. DC arc detection methods typically use time or frequency spectrum variations of the circuit current or voltage to differentiate the arcing event from other system events. Since practical systems include power electronics and maximum-power-point tracking, any detection scheme must perform robustly in the electrical environment that these components establish in the dc power system. A capacitor placed in parallel with the main system is an effective sensor for series arc fault detection and localization applicable in this complex electrical environment. This article shows that the analysis of the amplitude, polarity, and spectrum characteristics of the capacitor current and voltage resulting from perturbations caused by the arc provides an effective method to identify and localize faults. The detection accuracy of the proposed approach is 98.3% and the localization accuracy rate is 100% for the correctly detected faults.
{"title":"Development of a Fault Detection and Localization Algorithm for Photovoltaic Systems","authors":"Qing Xiong, A. Gattozzi, Xianyong Feng, Charles E. Penney, Chen Zhang, S. Ji, S. Strank, R. Hebner","doi":"10.1109/JPHOTOV.2023.3306073","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2023.3306073","url":null,"abstract":"Photovoltaic systems provide electrical power with reduced emissions at competitive costs compared to legacy systems. A low or medium voltage dc distribution system is usually used for solar integration. In dc systems, parallel and series arc faults are a safety concern. Thus, reliable and timely detection and mitigation of arc faults are critical. DC arc detection methods typically use time or frequency spectrum variations of the circuit current or voltage to differentiate the arcing event from other system events. Since practical systems include power electronics and maximum-power-point tracking, any detection scheme must perform robustly in the electrical environment that these components establish in the dc power system. A capacitor placed in parallel with the main system is an effective sensor for series arc fault detection and localization applicable in this complex electrical environment. This article shows that the analysis of the amplitude, polarity, and spectrum characteristics of the capacitor current and voltage resulting from perturbations caused by the arc provides an effective method to identify and localize faults. The detection accuracy of the proposed approach is 98.3% and the localization accuracy rate is 100% for the correctly detected faults.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"1 1","pages":"958-967"},"PeriodicalIF":3.0,"publicationDate":"2023-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91281366","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 : 2023-11-01DOI: 10.1109/JPHOTOV.2023.3308259
Angelos I. Nousdilis, G. Kryonidis, T. Papadopoulos
The intermittent and volatile nature of renewable energy sources (RESs) has introduced new technical challenges that affect the secure and reliable grid operation. These challenges can be tackled at the RES level by reducing power fluctuations with the use of power smoothing (PS) techniques. Several PS methods have been proposed in the literature to smooth RES output exploiting battery energy storage systems (BESSs). However, a comprehensive comparative evaluation of PS methods is missing. Moreover, the effect of the long-term PS operation on the BESS life is usually ignored in such analyses. This article proposes a methodology for the systematic evaluation of well-established PS techniques, comparing their effectiveness on the PS of photovoltaic output based on various signal metrics. In addition, an accurate aging model for lithium-ion batteries is employed to investigate the impact of PS on the BESS lifetime, highlighting the main parameters that influence capacity degradation.
{"title":"Comparative Evaluation of Solar Power Smoothing Techniques Considering Battery Degradation","authors":"Angelos I. Nousdilis, G. Kryonidis, T. Papadopoulos","doi":"10.1109/JPHOTOV.2023.3308259","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2023.3308259","url":null,"abstract":"The intermittent and volatile nature of renewable energy sources (RESs) has introduced new technical challenges that affect the secure and reliable grid operation. These challenges can be tackled at the RES level by reducing power fluctuations with the use of power smoothing (PS) techniques. Several PS methods have been proposed in the literature to smooth RES output exploiting battery energy storage systems (BESSs). However, a comprehensive comparative evaluation of PS methods is missing. Moreover, the effect of the long-term PS operation on the BESS life is usually ignored in such analyses. This article proposes a methodology for the systematic evaluation of well-established PS techniques, comparing their effectiveness on the PS of photovoltaic output based on various signal metrics. In addition, an accurate aging model for lithium-ion batteries is employed to investigate the impact of PS on the BESS lifetime, highlighting the main parameters that influence capacity degradation.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"69 1","pages":"951-957"},"PeriodicalIF":3.0,"publicationDate":"2023-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75990061","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 : 2023-11-01DOI: 10.1109/JPHOTOV.2023.3301674
Ilaria Matacena;Laura Lancellotti;Santolo Daliento;Brigida Alfano;Antonella De Maria;Vera La Ferrara;Lucia V. Mercaldo;Maria Lucia Miglietta;Tiziana Polichetti;Gabriella Rametta;Gennaro V. Sannino;Paola Delli Veneri;Pierluigi Guerriero
Characterizing the electron transport layer (ETL)/perovskite interface in perovskite solar cells (PSCs) is of paramount importance for their overall performance. In this article the effect of different concentrations of graphene nanoplatelets in addition to SnO2 is investigated by considering degradation over time. PSCs behavior is monitored by collecting dark current–voltage curves as fabricated and after two months. A deeper insight is gained through impedance spectroscopy analysis. From Nyquist plots equivalent circuit models and the corresponding time constants are extracted. Moreover, resistive part of the impedance associated with high frequency has been related to static shunt resistance, assessing one of the considered ETL doping concentration as the more suitable choice to reduce degradation.
{"title":"Impedance Spectroscopy of Perovskite Solar Cells With SnO2 Embedding Graphene Nanoplatelets","authors":"Ilaria Matacena;Laura Lancellotti;Santolo Daliento;Brigida Alfano;Antonella De Maria;Vera La Ferrara;Lucia V. Mercaldo;Maria Lucia Miglietta;Tiziana Polichetti;Gabriella Rametta;Gennaro V. Sannino;Paola Delli Veneri;Pierluigi Guerriero","doi":"10.1109/JPHOTOV.2023.3301674","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2023.3301674","url":null,"abstract":"Characterizing the electron transport layer (ETL)/perovskite interface in perovskite solar cells (PSCs) is of paramount importance for their overall performance. In this article the effect of different concentrations of graphene nanoplatelets in addition to SnO2 is investigated by considering degradation over time. PSCs behavior is monitored by collecting dark current–voltage curves as fabricated and after two months. A deeper insight is gained through impedance spectroscopy analysis. From Nyquist plots equivalent circuit models and the corresponding time constants are extracted. Moreover, resistive part of the impedance associated with high frequency has been related to static shunt resistance, assessing one of the considered ETL doping concentration as the more suitable choice to reduce degradation.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"13 6","pages":"866-872"},"PeriodicalIF":3.0,"publicationDate":"2023-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"71902906","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}
We report on crossing the 20% efficiency line for thin-film solar modules. The efficiency of our cadmium-free Cu(In,Ga)(S,Se) 2 (CIGSSe) mid-sized modules (30 × 30 cm 2 ) based on the cost-efficient AVANCIS stacked elemental layer – rapid thermal processing absorber process has evolved in the last two years reaching 19.6%, 19.8% and recently we have achieved an efficiency level of 20.3% as independently measured by NREL. The recent improvements were made possible by thorough variations in absorber composition and elemental distribution. The optimization of the absorber thickness, and of the band gap profile through the engineering of sulfur content and gradient at the absorber surface induces an improved absorber quality leading to a distinct increase in the product of short circuit current density and open circuit voltage (J SC × V OC ). Moreover, improving the absorber homogeneity and adjusting the absorber-buffer interface play an important role in enhancing the fill factor.
{"title":"Beyond 20% World Record Efficiency for Thin-Film Solar Modules","authors":"Hossam Elanzeery;Marko Stölzel;Patrick Eraerds;Peter Borowski;Hisham Aboulfadl;Alberto Lomuscio;Detlef Helmecke;Christian Schubbert;Souhaib Oueslati;Matej Hála;Julian Röder;Florian Giesl;Thomas Dalibor","doi":"10.1109/JPHOTOV.2023.3326559","DOIUrl":"10.1109/JPHOTOV.2023.3326559","url":null,"abstract":"We report on crossing the 20% efficiency line for thin-film solar modules. The efficiency of our cadmium-free Cu(In,Ga)(S,Se)\u0000<sub>2</sub>\u0000 (CIGSSe) mid-sized modules (30 × 30 cm\u0000<sup>2</sup>\u0000) based on the cost-efficient AVANCIS stacked elemental layer – rapid thermal processing absorber process has evolved in the last two years reaching 19.6%, 19.8% and recently we have achieved an efficiency level of 20.3% as independently measured by NREL. The recent improvements were made possible by thorough variations in absorber composition and elemental distribution. The optimization of the absorber thickness, and of the band gap profile through the engineering of sulfur content and gradient at the absorber surface induces an improved absorber quality leading to a distinct increase in the product of short circuit current density and open circuit voltage (J\u0000<sub>SC</sub>\u0000 × V\u0000<sub>OC</sub>\u0000). Moreover, improving the absorber homogeneity and adjusting the absorber-buffer interface play an important role in enhancing the fill factor.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"14 1","pages":"107-115"},"PeriodicalIF":3.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://ieeexplore.ieee.org/stamp/stamp.jsp?tp=&arnumber=10301701","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135260938","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 : 2023-10-30DOI: 10.1109/JPHOTOV.2023.3326560
João Gabriel Bessa;Michael Valerino;Matthew Muller;Mike Bergin;Leonardo Micheli;Florencia Almonacid;Eduardo F. Fernández
In this study, the impact of pollen as a PV soiling agent is investigated. The performance data of five utility-scale PV plants in North Carolina, USA, was collected and analyzed using two soiling extraction methods. Satellite and environmental data, including pollen counts, cropland, and vegetation, was also collected and analyzed to identify impacts to soiling losses. During the spring peak pollen season, performance losses of >15% were observed at all five sites. Partial performance recoveries following the pollen season were slow, with lack of correlation with rainfall. This means that the statistical soiling estimation methods that assume abrupt performance recovery from rain are not appropriate for pollen-impacted solar sites. When manual cleanings were performed on site the performance recovery ranged from 5% to 11% indicating persistent soiling impacts are present in this region. The results of this work provide new insights into the phenomenon of pollen deposition on PV systems, demonstrating that 1) soiling can also affect systems located in rainy locations and 2) that its effects cannot be determined using the current estimation methodologies.
{"title":"An Investigation on the Pollen-Induced Soiling Losses in Utility-Scale PV Plants","authors":"João Gabriel Bessa;Michael Valerino;Matthew Muller;Mike Bergin;Leonardo Micheli;Florencia Almonacid;Eduardo F. Fernández","doi":"10.1109/JPHOTOV.2023.3326560","DOIUrl":"10.1109/JPHOTOV.2023.3326560","url":null,"abstract":"In this study, the impact of pollen as a PV soiling agent is investigated. The performance data of five utility-scale PV plants in North Carolina, USA, was collected and analyzed using two soiling extraction methods. Satellite and environmental data, including pollen counts, cropland, and vegetation, was also collected and analyzed to identify impacts to soiling losses. During the spring peak pollen season, performance losses of >15% were observed at all five sites. Partial performance recoveries following the pollen season were slow, with lack of correlation with rainfall. This means that the statistical soiling estimation methods that assume abrupt performance recovery from rain are not appropriate for pollen-impacted solar sites. When manual cleanings were performed on site the performance recovery ranged from 5% to 11% indicating persistent soiling impacts are present in this region. The results of this work provide new insights into the phenomenon of pollen deposition on PV systems, demonstrating that 1) soiling can also affect systems located in rainy locations and 2) that its effects cannot be determined using the current estimation methodologies.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"14 1","pages":"178-184"},"PeriodicalIF":3.0,"publicationDate":"2023-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135261379","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 : 2023-10-27DOI: 10.1109/JPHOTOV.2023.3276935
Emre Karatas;Ralph Gottschalg
Photovoltaic devices degrade during their lifetime, just like any other technology. Degradation rates, and thus the lifetime of products, are currently not well understood. This lack of understanding results in stakeholders being exposed to unquantified risks and subsequently insufficient securities being set aside. It is shown that one cannot rely on a singular degradation rate of module's datasheet when it comes to assessing potential failure rates or warranty risks. Aging rates will vary in the field due to normal production variability. The existing approach that accepts a module type as reliable when a single certification test is passed cannot explain failures seen in the field nor provide any quantitative prediction. To address this problem, a methodology is developed that, in principle, predicts the likelihood of warranty claims in different operating environments. The method generates probability distributions of module performance for 25 years with typical degradation patterns seen for different degradation modes. The risk of failure is calculated from these distributions according to warranty conditions typical in the industry. The results show that over a quarter of the modules may be at risk of warranty failure at the end of warranty period. Furthermore, when the calculation is made considering that the degradation is exponential rather than linear, there is a risk of observing roughly five times more warranty cases five years after installation. Unlike current practices, this probabilistic warranty risk calculation approach can provide quantitative results, and help stakeholders better assess likely performance reduction of photovoltaic (PV) assets.
{"title":"Predicting Warranty Risk of PV Modules","authors":"Emre Karatas;Ralph Gottschalg","doi":"10.1109/JPHOTOV.2023.3276935","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2023.3276935","url":null,"abstract":"Photovoltaic devices degrade during their lifetime, just like any other technology. Degradation rates, and thus the lifetime of products, are currently not well understood. This lack of understanding results in stakeholders being exposed to unquantified risks and subsequently insufficient securities being set aside. It is shown that one cannot rely on a singular degradation rate of module's datasheet when it comes to assessing potential failure rates or warranty risks. Aging rates will vary in the field due to normal production variability. The existing approach that accepts a module type as reliable when a single certification test is passed cannot explain failures seen in the field nor provide any quantitative prediction. To address this problem, a methodology is developed that, in principle, predicts the likelihood of warranty claims in different operating environments. The method generates probability distributions of module performance for 25 years with typical degradation patterns seen for different degradation modes. The risk of failure is calculated from these distributions according to warranty conditions typical in the industry. The results show that over a quarter of the modules may be at risk of warranty failure at the end of warranty period. Furthermore, when the calculation is made considering that the degradation is exponential rather than linear, there is a risk of observing roughly five times more warranty cases five years after installation. Unlike current practices, this probabilistic warranty risk calculation approach can provide quantitative results, and help stakeholders better assess likely performance reduction of photovoltaic (PV) assets.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"13 6","pages":"945-950"},"PeriodicalIF":3.0,"publicationDate":"2023-10-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"71903032","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}
Net zero water withdrawal is a sustainable development strategy for manufacturing in water-stressed locations. A case study in Tamil Nadu, India shows that sustainable net zero water withdrawal photovoltaics (PV) manufacturing can be achieved by a) utilizing on-site wastewater treatment and zero liquid discharge units to maximize the usage of onsite reclaimed water, b) using offsite reclaimed water to meet the remaining water demand, and c) implementing continuous improvement in water conservation. Net zero water can be combined with net zero electricity to reduce the life cycle water footprint of PV modules by ∼60% while also reducing the life cycle carbon footprint by ∼40%. While crucial for managing local water and energy resources, net zero strategies have a relatively small (∼20%) impact on reducing the total multicriteria product footprint. Adding a third strategy of high value recycling with semiconductor recovery can achieve up to ∼65% reduction in the multicriteria PV module product environmental footprint covering health, ecosystem, and natural resource impact categories.
{"title":"Net Zero Water Withdrawal Strategies and Multicriteria Impacts for PV Manufacturing","authors":"Parikhit Sinha;Sunil Sajja;Tzy Wei Ooi;Sreenivas Jayaraman;Sukhwant Raju","doi":"10.1109/JPHOTOV.2023.3323777","DOIUrl":"10.1109/JPHOTOV.2023.3323777","url":null,"abstract":"Net zero water withdrawal is a sustainable development strategy for manufacturing in water-stressed locations. A case study in Tamil Nadu, India shows that sustainable net zero water withdrawal photovoltaics (PV) manufacturing can be achieved by a) utilizing on-site wastewater treatment and zero liquid discharge units to maximize the usage of onsite reclaimed water, b) using offsite reclaimed water to meet the remaining water demand, and c) implementing continuous improvement in water conservation. Net zero water can be combined with net zero electricity to reduce the life cycle water footprint of PV modules by ∼60% while also reducing the life cycle carbon footprint by ∼40%. While crucial for managing local water and energy resources, net zero strategies have a relatively small (∼20%) impact on reducing the total multicriteria product footprint. Adding a third strategy of high value recycling with semiconductor recovery can achieve up to ∼65% reduction in the multicriteria PV module product environmental footprint covering health, ecosystem, and natural resource impact categories.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"14 1","pages":"201-207"},"PeriodicalIF":3.0,"publicationDate":"2023-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134883972","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 : 2023-10-26DOI: 10.1109/JPHOTOV.2023.3324996
Ingrid L. Repins;Michael G. Deceglie;Timothy J. Silverman;David C. Miller;Dirk C. Jordan;Mike Woodhouse;Teresa M. Barnes
A forward-looking research opportunity number (RON) is defined for photovoltaic reliability researchers. The RON enables researchers to prioritize their efforts toward the highest impact. For a given degradation mode, the RON is based on three factors: the effect on levelized cost of electricity, the susceptibility of future module products, and the maturity of accelerated tests that can detect and quantify the mode. Reporting bias is avoided because the RON does not rely on polls. The RON is derived for three example cases: light and elevated temperature degradation, backsheet cracking, and antireflective coating abrasion. These examples demonstrate that targeted research has reduced the risk for these modes over the last several years.
为光伏可靠性研究人员定义了前瞻性研究机会编号（RON）。RON 使研究人员能够优先考虑影响最大的工作。对于给定的退化模式，RON 基于三个因素：对平准化电力成本的影响、未来组件产品的易损性以及可检测和量化该模式的加速测试的成熟度。由于 RON 不依赖于民意调查，因此避免了报告偏差。RON 是针对三个实例得出的：光照和高温降解、背板开裂和抗反射涂层磨损。这些示例表明，在过去几年中，有针对性的研究已经降低了这些模式的风险。
{"title":"Setting Priorities for Photovoltaic Reliability Research Using Criticality Analysis","authors":"Ingrid L. Repins;Michael G. Deceglie;Timothy J. Silverman;David C. Miller;Dirk C. Jordan;Mike Woodhouse;Teresa M. Barnes","doi":"10.1109/JPHOTOV.2023.3324996","DOIUrl":"10.1109/JPHOTOV.2023.3324996","url":null,"abstract":"A forward-looking research opportunity number (RON) is defined for photovoltaic reliability researchers. The RON enables researchers to prioritize their efforts toward the highest impact. For a given degradation mode, the RON is based on three factors: the effect on levelized cost of electricity, the susceptibility of future module products, and the maturity of accelerated tests that can detect and quantify the mode. Reporting bias is avoided because the RON does not rely on polls. The RON is derived for three example cases: light and elevated temperature degradation, backsheet cracking, and antireflective coating abrasion. These examples demonstrate that targeted research has reduced the risk for these modes over the last several years.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"14 1","pages":"46-52"},"PeriodicalIF":3.0,"publicationDate":"2023-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134883634","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}
Moisture plays a critical role in the degradation process of photovoltaic (PV) modules in field conditions. A commonly used approach is to evaluate the properties of PV materials by conducting tests in climatic chambers, and then apply the Fickian diffusion model in simulations to replicate field conditions, however, without experimental verification. This study describes an experimental setup for in situ measurement of moisture in fielded minimodules, using miniature temperature and humidity sensors encapsulated within the modules. Five identical setups are deployed in different climatic regions around the world, enabling a quantitative evaluation of moisture diffusion in the field and a comparison of different climates. The relative humidity measured beside the cell follow weekly weather trends due to breathable backsheet, whereas the sensors in front of the cell react much slower to outside changes and follow seasonal trends. We show that a single 2-D simulation, which is a standard practice in published studies, is insufficient to accurately depict moisture diffusion in front of the cell. Therefore, a two-stage 2-D simulation model, combining Fickian diffusion in vertical and horizontal cross section with carefully set boundary conditions, was introduced. A comparison with measurement results showed the simulation approach to be a good compromise between the simulation accuracy and speed. Finally, the results underscore the significance of understanding the local microclimate surrounding the modules, including the interface between air and backsheet, which is necessary for precise moisture diffusion simulations.
{"title":"Measurement and Simulation of Moisture Ingress in PV Modules in Various Climates","authors":"Stefan Mitterhofer;Jan Slapšak;Alexander Astigarraga;David Moser;Guillermo Oviedo Hernandez;Paolo Vincenzo Chiantore;Wei Luo;Yong Sheng Khoo;Jorge Rabanal-Arabach;Edward Fuentealba;Pablo Ferrada;Mauricio Trigo Gonzalez;Julián Ascencio-Vásquez;Marko Topič;Marko Jankovec","doi":"10.1109/JPHOTOV.2023.3323808","DOIUrl":"10.1109/JPHOTOV.2023.3323808","url":null,"abstract":"Moisture plays a critical role in the degradation process of photovoltaic (PV) modules in field conditions. A commonly used approach is to evaluate the properties of PV materials by conducting tests in climatic chambers, and then apply the Fickian diffusion model in simulations to replicate field conditions, however, without experimental verification. This study describes an experimental setup for in situ measurement of moisture in fielded minimodules, using miniature temperature and humidity sensors encapsulated within the modules. Five identical setups are deployed in different climatic regions around the world, enabling a quantitative evaluation of moisture diffusion in the field and a comparison of different climates. The relative humidity measured beside the cell follow weekly weather trends due to breathable backsheet, whereas the sensors in front of the cell react much slower to outside changes and follow seasonal trends. We show that a single 2-D simulation, which is a standard practice in published studies, is insufficient to accurately depict moisture diffusion in front of the cell. Therefore, a two-stage 2-D simulation model, combining Fickian diffusion in vertical and horizontal cross section with carefully set boundary conditions, was introduced. A comparison with measurement results showed the simulation approach to be a good compromise between the simulation accuracy and speed. Finally, the results underscore the significance of understanding the local microclimate surrounding the modules, including the interface between air and backsheet, which is necessary for precise moisture diffusion simulations.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"14 1","pages":"140-148"},"PeriodicalIF":3.0,"publicationDate":"2023-10-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134981269","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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