The accumulation of dust and dirt on solar photovoltaic (PV) panels, known as soiling, reduces energy generation and conversion efficiency of a PV plant. Therefore, regular cleaning is essential to maintain optimal plant performance and economic viability. Fixed-interval cleaning schedules become uneconomical during periods such as low-insolation, rainy, or cloudy events. This study proposes a data-driven method to estimate the soiling ratio (SR) for a 504-kWp rooftop PV plant in India using power, temperature, and irradiance data. A PV panel temperature estimation model is employed, based on ambient temperature and solar irradiance, which simplifies the process by eliminating the need for direct temperature measurements. The analysis reveals that regular cleaning is essential despite rainfall, with energy losses due to soiling ranging from 32% to 47% across inverters, with soiling rates of 4.6–5.5% per day. A dynamic cleaning schedule, considering weather and soiling conditions, was developed to reduce these losses. Economic evaluation demonstrated that manual cleaning following the proposed dynamic schedule is cost effective, with profit margins of 48–77%, comparing energy gain and cleaning cost. Compared with fixed-interval cleaning, the proposed method maintained the same average SR but yielded 25–49% higher profitability across inverters.
{"title":"Data-Driven Soiling Estimation and Optimized Cleaning Strategies for Industrial Rooftop PV Systems","authors":"Ankit Pal;Saravana Ilango Ganesan;Maddikara Jaya Bharata Reddy","doi":"10.1109/JPHOTOV.2025.3527124","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2025.3527124","url":null,"abstract":"The accumulation of dust and dirt on solar photovoltaic (PV) panels, known as soiling, reduces energy generation and conversion efficiency of a PV plant. Therefore, regular cleaning is essential to maintain optimal plant performance and economic viability. Fixed-interval cleaning schedules become uneconomical during periods such as low-insolation, rainy, or cloudy events. This study proposes a data-driven method to estimate the soiling ratio (SR) for a 504-kWp rooftop PV plant in India using power, temperature, and irradiance data. A PV panel temperature estimation model is employed, based on ambient temperature and solar irradiance, which simplifies the process by eliminating the need for direct temperature measurements. The analysis reveals that regular cleaning is essential despite rainfall, with energy losses due to soiling ranging from 32% to 47% across inverters, with soiling rates of 4.6–5.5% per day. A dynamic cleaning schedule, considering weather and soiling conditions, was developed to reduce these losses. Economic evaluation demonstrated that manual cleaning following the proposed dynamic schedule is cost effective, with profit margins of 48–77%, comparing energy gain and cleaning cost. Compared with fixed-interval cleaning, the proposed method maintained the same average SR but yielded 25–49% higher profitability across inverters.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 2","pages":"353-361"},"PeriodicalIF":2.5,"publicationDate":"2025-01-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143455249","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 : 2025-01-09DOI: 10.1109/JPHOTOV.2024.3523546
Chiara Barretta;Astrid E. Macher;Marc Köntges;Julian Ascencio-Vásquez;Marko Topič;Gernot Oreski
A damage analysis was conducted on photovoltaic modules with identical bill of materials exposed to different climates: Cfb moderate and Af tropical, according to the Köppen-Geiger climate classification. The combination of high temperature, relative humidity, and high ultraviolet (UV) radiation was the cause of severe degradation for the modules exposed to tropical climates (TR), whereas the module exposed to a moderate climate did not experience a significant loss in performance. The modules installed in TR, on the contrary, showed significant power degradation after approximately 8 years of exposure, primarily attributed to acetic acid-related degradation modes. Encapsulant samples were extracted from the selected modules and characterized to determine changes in chemical structure, thermal stability, and consumption of additives and stabilizers. The results of qualitative additive analysis showed that the UV absorber was no longer detectable in the front encapsulant extracted from modules exposed in TR. The consumption of the stabilizers was considered as the main cause of reduction of molar mass. The presence of acetic acid was evident in both electroluminescence images and ion chromatography results. While differential scanning calorimetry successfully detected a reduction in molar mass, thermogravimetric analysis, and infrared spectroscopy proved unsuitable for identifying chain scission phenomena.
{"title":"Effect of Encapsulant Degradation on Photovoltaic Modules Performances Installed in Different Climates","authors":"Chiara Barretta;Astrid E. Macher;Marc Köntges;Julian Ascencio-Vásquez;Marko Topič;Gernot Oreski","doi":"10.1109/JPHOTOV.2024.3523546","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2024.3523546","url":null,"abstract":"A damage analysis was conducted on photovoltaic modules with identical bill of materials exposed to different climates: Cfb moderate and Af tropical, according to the Köppen-Geiger climate classification. The combination of high temperature, relative humidity, and high ultraviolet (UV) radiation was the cause of severe degradation for the modules exposed to tropical climates (TR), whereas the module exposed to a moderate climate did not experience a significant loss in performance. The modules installed in TR, on the contrary, showed significant power degradation after approximately 8 years of exposure, primarily attributed to acetic acid-related degradation modes. Encapsulant samples were extracted from the selected modules and characterized to determine changes in chemical structure, thermal stability, and consumption of additives and stabilizers. The results of qualitative additive analysis showed that the UV absorber was no longer detectable in the front encapsulant extracted from modules exposed in TR. The consumption of the stabilizers was considered as the main cause of reduction of molar mass. The presence of acetic acid was evident in both electroluminescence images and ion chromatography results. While differential scanning calorimetry successfully detected a reduction in molar mass, thermogravimetric analysis, and infrared spectroscopy proved unsuitable for identifying chain scission phenomena.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 2","pages":"290-296"},"PeriodicalIF":2.5,"publicationDate":"2025-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143455097","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}
The yield of photovoltaic (PV) modules is influenced by various environmental factors, particularly solar irradiance and temperature. However, the measured solar irradiance does not accurately represent the real light intensity absorbed by different types of solar cells, and the measured temperature does not represent the actual cell temperature in PV modules. In this article, equivalent irradiance and temperature are proposed and used to improve the accuracy of output performance estimation of PV modules. First, equivalent irradiance and temperature under different operating condition are obtained by fitting measured I–V data by using the guaranteed convergence particle swarm optimization. Second, the relationship between the equivalent irradiance and temperature and environmental factors is established by an artificial neural network (ANN) model. Two types of ANNs with different input vector are proposed to calculated equivalent irradiance and temperature. The accuracy of the proposed method was validated by experimental data for four different types of PV modules under wide operating conditions.
{"title":"A Novel Method for Performance Estimation of PV Modules Using Equivalent Irradiance and Temperature","authors":"Jinlong Zhang;Zhenguang Liang;Yunpeng Zhang;Hai Zhou;Ji Wu;Honglu Zhu","doi":"10.1109/JPHOTOV.2024.3521090","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2024.3521090","url":null,"abstract":"The yield of photovoltaic (PV) modules is influenced by various environmental factors, particularly solar irradiance and temperature. However, the measured solar irradiance does not accurately represent the real light intensity absorbed by different types of solar cells, and the measured temperature does not represent the actual cell temperature in PV modules. In this article, equivalent irradiance and temperature are proposed and used to improve the accuracy of output performance estimation of PV modules. First, equivalent irradiance and temperature under different operating condition are obtained by fitting measured <italic>I–V</i> data by using the guaranteed convergence particle swarm optimization. Second, the relationship between the equivalent irradiance and temperature and environmental factors is established by an artificial neural network (ANN) model. Two types of ANNs with different input vector are proposed to calculated equivalent irradiance and temperature. The accuracy of the proposed method was validated by experimental data for four different types of PV modules under wide operating conditions.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 2","pages":"274-279"},"PeriodicalIF":2.5,"publicationDate":"2025-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143455099","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 : 2025-01-09DOI: 10.1109/JPHOTOV.2024.3521121
Mauro Pravettoni;Min Hsian Saw;Muhammad Nabil Bin Abdul Aziz;Stephen En Rong Tay
In Part 1 of our article, we presented a method to quantify the incidence angle modifier (IAM) of photovoltaic (PV) devices, which differs from the methods proposed in IEC 61853-2 through the following: it utilizes a spot-area irradiation, delivered by an optical fiber system, a customized angle probe holder, and a current-to-voltage converter. Part 1 focused on single-cell devices and presented the validation of the new method on two different cell architectures. In Part 2, we generalize that method to commercial-size silicon PV modules, mirroring by the approach already used for module-level spectral responsivity measurements described in IEC 60904-8:2014. The proposed method is motivated by inclusion in the currently ongoing revision of IEC 61853-2, providing research centers and testing laboratories with an additional option to perform IAM measurements indoors. The reproducibility of the proposed method is addressed in this work via interlaboratory comparison with a different measurement method for the same quantity and with a detailed uncertainty analysis.
{"title":"A Spot-Area Method to Evaluate the Incidence Angle Modifier of Photovoltaic Devices-Part 2: Modules (Differential Method)","authors":"Mauro Pravettoni;Min Hsian Saw;Muhammad Nabil Bin Abdul Aziz;Stephen En Rong Tay","doi":"10.1109/JPHOTOV.2024.3521121","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2024.3521121","url":null,"abstract":"In Part 1 of our article, we presented a method to quantify the incidence angle modifier (IAM) of photovoltaic (PV) devices, which differs from the methods proposed in IEC 61853-2 through the following: it utilizes a spot-area irradiation, delivered by an optical fiber system, a customized angle probe holder, and a current-to-voltage converter. Part 1 focused on single-cell devices and presented the validation of the new method on two different cell architectures. In Part 2, we generalize that method to commercial-size silicon PV modules, mirroring by the approach already used for module-level spectral responsivity measurements described in IEC 60904-8:2014. The proposed method is motivated by inclusion in the currently ongoing revision of IEC 61853-2, providing research centers and testing laboratories with an additional option to perform IAM measurements indoors. The reproducibility of the proposed method is addressed in this work via interlaboratory comparison with a different measurement method for the same quantity and with a detailed uncertainty analysis.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 2","pages":"280-289"},"PeriodicalIF":2.5,"publicationDate":"2025-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143455240","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 : 2025-01-06DOI: 10.1109/JPHOTOV.2024.3521089
Jeremiah Reagan;Brandi McKuin;Sarah Kurtz
In this article, we assessed five reflector materials for hypothetical vertical bifacial arrays as a solar canal technology option. We screened the materials (CoverMax, CoverTuff, polyvinyl chloride (PVC) Poly, polyester canvas, and Vivosun aluminized Mylar) for reflectivity, tensile strength to minimum mounting load, vapor barrier performance to reduce evaporation, and energy production. Vivosun had the highest reflectivity (albedo of 0.87–0.93) and increased annual energy production more than 40% compared with a system without reflector, but plastically deformed under tensile strength testing. All materials reduced evaporation at least fivefold compared with the control. Following our preliminary assessment, we calculated the levelized cost of electricity of a hypothetical vertical bifacial array with two height configurations (short system at 2 m and tall system at 3 m) and four hybrid reflectors (fabricated from strong base layer materials with a top layer of Vivosun) and compared these results with systems with single-material reflectors and with systems without reflectors. We found that the tall system with a hybrid reflector made from PVC Poly had the lowest levelized cost of electricity. However, when considering other performance metrics, such as tensile strength and vapor barrier performance, a hybrid reflector made from CoverMax emerged as the best candidate of the options considered.
{"title":"Comparison of Reflector Materials for a Vertical Bifacial Solar Canal","authors":"Jeremiah Reagan;Brandi McKuin;Sarah Kurtz","doi":"10.1109/JPHOTOV.2024.3521089","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2024.3521089","url":null,"abstract":"In this article, we assessed five reflector materials for hypothetical vertical bifacial arrays as a solar canal technology option. We screened the materials (CoverMax, CoverTuff, polyvinyl chloride (PVC) Poly, polyester canvas, and Vivosun aluminized Mylar) for reflectivity, tensile strength to minimum mounting load, vapor barrier performance to reduce evaporation, and energy production. Vivosun had the highest reflectivity (albedo of 0.87–0.93) and increased annual energy production more than 40% compared with a system without reflector, but plastically deformed under tensile strength testing. All materials reduced evaporation at least fivefold compared with the control. Following our preliminary assessment, we calculated the levelized cost of electricity of a hypothetical vertical bifacial array with two height configurations (short system at 2 m and tall system at 3 m) and four hybrid reflectors (fabricated from strong base layer materials with a top layer of Vivosun) and compared these results with systems with single-material reflectors and with systems without reflectors. We found that the tall system with a hybrid reflector made from PVC Poly had the lowest levelized cost of electricity. However, when considering other performance metrics, such as tensile strength and vapor barrier performance, a hybrid reflector made from CoverMax emerged as the best candidate of the options considered.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 2","pages":"343-352"},"PeriodicalIF":2.5,"publicationDate":"2025-01-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143455264","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 : 2024-12-24DOI: 10.1109/JPHOTOV.2024.3506132
{"title":"Golden List of Reviewers","authors":"","doi":"10.1109/JPHOTOV.2024.3506132","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2024.3506132","url":null,"abstract":"","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 1","pages":"200-203"},"PeriodicalIF":2.5,"publicationDate":"2024-12-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://ieeexplore.ieee.org/stamp/stamp.jsp?tp=&arnumber=10814113","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142880301","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 : 2024-12-16DOI: 10.1109/JPHOTOV.2024.3496512
Kuan Liu;David C. Miller;Nick Bosco;Jimmy M. Newkirk;Tomoko Sakamoto;Reinhold H. Dauskardt
Degradation of photovoltaic (PV) module encapsulant characteristics that lead to mechanical embrittlement and delamination remains a cause of failure in solar installations. A multiscale reliability model connecting the encapsulant mechanical and fracture properties to the degraded molecular structure and interfacial bonding to adjacent solar cell and glass substrates was previously published. The model, developed primarily for poly(ethylene-co-vinyl acetate) acetate (EVA) encapsulants, remains to be experimentally validated. Determining the degradation and crosslinking kinetics of alternative encapsulants, such as polyolefin elastomer (POE) and EVA/POE/EVA composites (EPE), can generalize the model. In this work, we subject fully cured EVA, POE, and EPE encapsulants to accelerated thermal aging to determine how high temperatures impact reaction kinetics. An increase in gel content (crosslinking) and decrease in crystallinity of the encapsulants under hot-aerobic (90 °C, 22% RH) and hot-anaerobic (90 °C, sealed in N2 air) aging were observed, even in the absence of UV and crosslinking initiators. Fourier transform infrared spectroscopy (FTIR)-attenuated total reflectance analysis showed insignificant encapsulant degradation, demonstrating the critical role of UV and moisture in accelerating degradation. Adhesion testing performed on coupon-level specimens (cell/encapsulant/glass laminates) showed decreases in adhesion energy, Gc, from 5000 h of hot-dry (90 °C, ∼1% RH) and hot-humid (90 °C, 60% RH) aging. POE coupons demonstrated the best stability, followed by EPE then EVA. For EVA and POE, hot-humid aged coupons experienced a larger decrease in Gc due to enhanced hydrolytic degradation. Hot-dry aging condition demonstrated that thermal degradation of the interface could be significant even if the encapsulant experiences negligible degradation in the absence of UV and elevated humidity.
{"title":"Investigating the Crosslinking, Degradation, and Adhesion Behavior of Photovoltaic Encapsulants Under Thermal Accelerated Aging","authors":"Kuan Liu;David C. Miller;Nick Bosco;Jimmy M. Newkirk;Tomoko Sakamoto;Reinhold H. Dauskardt","doi":"10.1109/JPHOTOV.2024.3496512","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2024.3496512","url":null,"abstract":"Degradation of photovoltaic (PV) module encapsulant characteristics that lead to mechanical embrittlement and delamination remains a cause of failure in solar installations. A multiscale reliability model connecting the encapsulant mechanical and fracture properties to the degraded molecular structure and interfacial bonding to adjacent solar cell and glass substrates was previously published. The model, developed primarily for poly(ethylene-co-vinyl acetate) acetate (EVA) encapsulants, remains to be experimentally validated. Determining the degradation and crosslinking kinetics of alternative encapsulants, such as polyolefin elastomer (POE) and EVA/POE/EVA composites (EPE), can generalize the model. In this work, we subject fully cured EVA, POE, and EPE encapsulants to accelerated thermal aging to determine how high temperatures impact reaction kinetics. An increase in gel content (crosslinking) and decrease in crystallinity of the encapsulants under hot-aerobic (90 °C, 22% RH) and hot-anaerobic (90 °C, sealed in N<sub>2</sub> air) aging were observed, even in the absence of UV and crosslinking initiators. Fourier transform infrared spectroscopy (FTIR)-attenuated total reflectance analysis showed insignificant encapsulant degradation, demonstrating the critical role of UV and moisture in accelerating degradation. Adhesion testing performed on coupon-level specimens (cell/encapsulant/glass laminates) showed decreases in adhesion energy, <italic>G<sub>c</sub></i>, from 5000 h of hot-dry (90 °C, ∼1% RH) and hot-humid (90 °C, 60% RH) aging. POE coupons demonstrated the best stability, followed by EPE then EVA. For EVA and POE, hot-humid aged coupons experienced a larger decrease in <italic>G<sub>c</sub></i> due to enhanced hydrolytic degradation. Hot-dry aging condition demonstrated that thermal degradation of the interface could be significant even if the encapsulant experiences negligible degradation in the absence of UV and elevated humidity.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 2","pages":"309-319"},"PeriodicalIF":2.5,"publicationDate":"2024-12-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143455239","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 : 2024-12-04DOI: 10.1109/JPHOTOV.2024.3507079
António J. N. Oliveira;Bin Du;Kevin D. Dobson;Jennifer P. Teixeira;Maria R. P. Correia;Pedro M. P. Salomé;William N. Shafarman
The conversion efficiency of CdTe solar cells may be improved by bandgap engineering, i.e., changing the bandgap value through the addition of Se in the absorber. The Se alloying enables a short-circuit current density improvement, as it leads to a bandgap energy value decrease. Furthermore, it has been associated with increased minority carrier lifetimes, assuring high open-circuit voltage values. An Se gradient profile control can further optimize the solar cell performance. Thus, an optical model baseline of the CdSexTe1−x (CST) compound was developed. Spectroscopic ellipsometry measurements were conducted to accurately extract the optical constants of ten CST layers deposited through coevaporation with x varying from 0 to 1. Using the measured dielectric function spectra from the discrete CST layers with varying x, and considering the composition-induced shift in the critical point energies, an energy-shift model was employed to develop the accurate optical library for the CST compound for any x value to provide data for future modeling and optimization. The library accuracy was validated through optical simulations of the quantum efficiency of a graded CST solar cell using the finite-difference time-domain method by replicating the Se profile in the absorber layer measured through secondary ion mass spectrometry.
{"title":"Development of an Optical Library for Coevaporated CdSexTe1−x","authors":"António J. N. Oliveira;Bin Du;Kevin D. Dobson;Jennifer P. Teixeira;Maria R. P. Correia;Pedro M. P. Salomé;William N. Shafarman","doi":"10.1109/JPHOTOV.2024.3507079","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2024.3507079","url":null,"abstract":"The conversion efficiency of CdTe solar cells may be improved by bandgap engineering, i.e., changing the bandgap value through the addition of Se in the absorber. The Se alloying enables a short-circuit current density improvement, as it leads to a bandgap energy value decrease. Furthermore, it has been associated with increased minority carrier lifetimes, assuring high open-circuit voltage values. An Se gradient profile control can further optimize the solar cell performance. Thus, an optical model baseline of the CdSe<italic><sub>x</sub></i>Te<sub>1−</sub><italic><sub>x</sub></i> (CST) compound was developed. Spectroscopic ellipsometry measurements were conducted to accurately extract the optical constants of ten CST layers deposited through coevaporation with <italic>x</i> varying from 0 to 1. Using the measured dielectric function spectra from the discrete CST layers with varying <italic>x</i>, and considering the composition-induced shift in the critical point energies, an energy-shift model was employed to develop the accurate optical library for the CST compound for any <italic>x</i> value to provide data for future modeling and optimization. The library accuracy was validated through optical simulations of the quantum efficiency of a graded CST solar cell using the finite-difference time-domain method by replicating the Se profile in the absorber layer measured through secondary ion mass spectrometry.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 2","pages":"252-260"},"PeriodicalIF":2.5,"publicationDate":"2024-12-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143455248","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 : 2024-12-04DOI: 10.1109/JPHOTOV.2024.3501403
Preeti Kumari Sahu;Efstratios I. Batzelis;Chandan Chakraborty;J. N. Roy
Although the bifacial photovoltaic (PV) module is now a mature technology, there still exists a gap in the literature on its electrical modeling and equivalent circuit representation. Most published studies have mainly focused on the photocurrent while overlooking other crucial parameters for the electrical response of the module. Even so, the photocurrent of the bifacial module is simplistically treated as the sum of individual currents of the front and rear sides, a hypothesis challenged in this study. Notably, our research has uncovered a discrepancy that can exceed 15%, and we address this issue by introducing a correction factor in this article. This article introduces a comprehensive electrical model that effectively integrates bifacial PV modules' front and rear sides into a single $-$ circuit representation. This novel model adopts the single $-$ diode equivalent circuit, formulating each of the five parameters as a function of the individual side's parameters. Indoor and outdoor measurements validate the accuracy improvement brought by this model, which can benefit energy yield studies and our theoretical understanding of bifacial PV systems.
{"title":"Electrical Modeling of Bifacial PV Modules","authors":"Preeti Kumari Sahu;Efstratios I. Batzelis;Chandan Chakraborty;J. N. Roy","doi":"10.1109/JPHOTOV.2024.3501403","DOIUrl":"https://doi.org/10.1109/JPHOTOV.2024.3501403","url":null,"abstract":"Although the bifacial photovoltaic (PV) module is now a mature technology, there still exists a gap in the literature on its electrical modeling and equivalent circuit representation. Most published studies have mainly focused on the photocurrent while overlooking other crucial parameters for the electrical response of the module. Even so, the photocurrent of the bifacial module is simplistically treated as the sum of individual currents of the front and rear sides, a hypothesis challenged in this study. Notably, our research has uncovered a discrepancy that can exceed 15%, and we address this issue by introducing a correction factor in this article. This article introduces a comprehensive electrical model that effectively integrates bifacial PV modules' front and rear sides into a single \u0000<inline-formula><tex-math>$-$</tex-math></inline-formula>\u0000 circuit representation. This novel model adopts the single \u0000<inline-formula><tex-math>$-$</tex-math></inline-formula>\u0000 diode equivalent circuit, formulating each of the five parameters as a function of the individual side's parameters. Indoor and outdoor measurements validate the accuracy improvement brought by this model, which can benefit energy yield studies and our theoretical understanding of bifacial PV systems.","PeriodicalId":445,"journal":{"name":"IEEE Journal of Photovoltaics","volume":"15 1","pages":"117-125"},"PeriodicalIF":2.5,"publicationDate":"2024-12-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142880300","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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