Evaluation of solar energy potential and PV module performance in the Gobi Desert of Mongolia

Adiyabat, Amarbayar; Kurokawa, Kosuke; Otani, Kenji; Enebish, N.; Batsukh, G.; Battushig, Mishiglunden; Ochirvaani, Dorjsuren; Ganbat, Bathuu

doi:10.1002/pip.692

Cited by 30 publications

(19 citation statements)

References 2 publications

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“…The Research Center for Photovoltaics (RCPV), National Institute of Advanced Industrial Science and Technology (AIST) has performed outdoor performance measurements of various kinds of PV modules at different locations in Asia as shown in Figure 1: Sainshand, Mongolia in collaboration with National University of Mongolia (NUM) and National Renewable Energy Center of Mongolia (NREC) since October 2002 10, AIST Tsukuba in Japan since July 2004, Bangkok, Thailand in collaboration with National Science and Technology Development Agency (NSTDA) since January 2006 11, New Delhi, India in collaboration with Solar Energy Centre (SEC) and National Physical Laboratories (NPL) since January 2009, and AIST Kyushu in Japan since February 2009. In particular, the outdoor measurements at AIST Kyushu are planning to be extended up to a total of 100 kW composed of both PV modules and PV systems.…”

Section: Introductionmentioning

confidence: 99%

Long‐term performance degradation of various kinds of photovoltaic modules under moderate climatic conditions

Ishii

Takashima

Otani

2011

Progress in Photovoltaics

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Various kinds of photovoltaic (PV) modules have been developed and practically operated as PV systems up to present. Investigation of the long‐term reliability of PV modules is indispensable for the use of PV systems as reliable energy sources. In this study, we show the results of outdoor exposure test in which the performance of 14 PV modules composed of five different kinds made by six different PV manufacturers have been measured since July 2004. The average performance is calculated in each year from 2005 to 2008, and the performance degradation is quantitatively evaluated. The results are that the magnitude of the performance degradation can be clearly classified by the kinds of the PV modules. The performance difference of the single‐crystalline silicon (sc‐Si) modules between 2005 and 2008 is from 1.9% to 2.8%. Polycrystalline silicon (pc‐Si) modules show performance degradation from 0.7% to 1.4%. The performance of an amorphous silicon/crystalline silicon (a‐Si:H/c‐Si) decreased by 0.7%. Although a pair of a‐Si modules had been already exposed to sunlight for about 6 months, the pair of modules show 4.4% of performance degradation. More than half of the performance degradation happened during the initial period from 2005 to 2006. This indicates that it takes about 2 years until the performance of a‐Si modules is stable. The performance is quite stable after 2006. Interestingly, the performance of the cupper indium gallium diselenide modules in 2008 is about 0.8% higher than that in 2005. Copyright © 2010 John Wiley & Sons, Ltd.

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Section: Introductionmentioning

confidence: 99%

Long‐term performance degradation of various kinds of photovoltaic modules under moderate climatic conditions

Ishii

Takashima

Otani

2011

Progress in Photovoltaics

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“…1,2 The converted heat overheats Nomenclature: A, = total area of photovoltaic (PV) solar cell (m 2 ); C p , = specific heat (J kg −1 K −1 ); E p , = module's electrical power (W); E in , = received energy by solar cell (W); E t , = thermal energy in the system (W); E l , = lost energy from glass layer to ambient (W); G, = solar irradiance (W m −2 ); k, = thermal conductivity (W m −1 K −1 ); T amb , = ambient temperature (°C); T f , = water temperature (°C); T g , = glass temperature (°C); T he , = heat exchanger temperature (°C); T in , = inlet temperature (°C); T out , = outlet temperature (°C); T r , = reference temperature (°C); T s , = side boundary temperature (°C); T sc , = cell temperature (°C); T td , = Tedlar temperature (°C); U he , = heat loss coefficient from back surface to air (W m −2 K −1 ); U sca , = heat loss coefficient from glass to air (W m −2 K −1 ); U t , = heat transfer coefficient inside photovoltaic/thermal (PVT) surfaces (W m −2 K −1 ); V in , = input velocity of water (m s −1 ) Greek symbols: α g , = glass absorptivity; α sc , = PVT module absorptivity; τ g , = transmitivity of glass; ε g , = emissivity of glass; ρ, = density (kg m −3 ); μ sc , = thermal coefficient of cell efficiency (%/°C); η sc , = reference electrical efficiency of PV cell; η e , = PV electrical efficiency; η t , = PVT efficiency; η tot , = PVT overall efficiency the PV system and reduces its efficiency. 18,19 For Malaysia's climate condition, the performance of amorphous silicon PV cell is found better. Generally, a heat exchanger is attached to the PV Tedlar surface, and air/water is considered as cooling fluids to collect heat from this system.…”

Section: Introductionmentioning

confidence: 99%

Effect of high irradiation on photovoltaic power and energy

2017

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Summary Solar photovoltaics (PV) is a promising solution to combat against energy crisis and environmental pollution. However, the high manufacturing cost of solar cells along with the huge area required for well‐sized PV power plants are the two major issues for the sustainable expansion of this technology. Concentrator technology is one of the solutions of the abovementioned problem. As concentrating the solar radiation over a single cell is now a proven technology, so attempt has been made in this article to extend this concept over PV module. High irradiation intensity from 1000 to 3000 W/m2 has been investigated to measure the power and energy of PV cell. The numerical simulation has been conducted using finite element technique. At 3000 W/m2 irradiation, the electrical power increases by about 190 W compared with 63 W at irradiation level of 1000 W/m2. At the same time, at 3000 W/m2 irradiation, the thermal energy increases by about 996 W compared with 362 W at 1000 W/m2 irradiation. Electrical power and thermal energy are enhanced by about 6.4 and 31.3 W, respectively, for each 100‐W/m2 increase of solar radiation. The overall energy is increased by about 179.06% with increasing irradiation level from 1000 to 3000 W/m2. It is concluded that the effect of high solar radiation using concentrator can significantly improve the overall output of the PV module.

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“…Most of the above-mentioned models require either detailed data [26,[30][31][32][33][34][35][36][37] and are complicated to use [35,36] or restricted in economic performance evaluation [17][18][19][20][21]41]. These limitations of the mentioned literature are barrier in easy manipulation of the system performance.…”

Section: Introductionmentioning

confidence: 99%

“…Ronak et al [40] observed that performance of amorphous silicon is well under Malaysia's tropical hot and humid climate. Adiyabat et al [41] showed that a PV module with a high-temperature coefficient, such as crystalline silicon, is advantageous for use in the Gobi Desert area.…”

Section: Introductionmentioning

confidence: 99%

Mathematical method to find best suited PV technology for different climatic zones of India

Chakraborty

Kumar

Haldkar

et al. 2017

Int J Energy Environ Eng

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This paper presents a reliable mathematical method to predict the energy generation from grid connected photovoltaic plant of different commercially used technologies in different zones of India. Global horizontal insolation (GHI) and daytime temperature are the two major parameters affecting the output of photovoltaic (PV) plant. Depending on those two major parameters, India is classified into 15 climatic zones. Typical Meteorological Year data were collected from National Renewable Energy Laboratory to classify India in different climatic zones. Energy generation of different commercially used PV technologies in different climatic zones of India is predicted using proposed mathematical method. These results show a decisive study to choose the best PV technology for different climatic zones of India. Results predict that in almost all climatic zones, amorphous silicon (a-Si) is the best suitable PV technology. In very low-temperature zones, irrespective of GHI, the second best suitable PV technology is mono and cadmium telluride (CdTe) as generation from these two technologies is same. Whereas in other climatic zones, after a-Si the best suitable is CdTe PV technology. Predicted energy generation is validated with the 1-year generation of 2014 from 15 working PV plants of different technologies. Predicted generation is in good co-relation with the actual real-time generation from the PV plants.

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Evaluation of solar energy potential and PV module performance in the Gobi Desert of Mongolia

Cited by 30 publications

References 2 publications

Long‐term performance degradation of various kinds of photovoltaic modules under moderate climatic conditions

Long‐term performance degradation of various kinds of photovoltaic modules under moderate climatic conditions

Effect of high irradiation on photovoltaic power and energy

Mathematical method to find best suited PV technology for different climatic zones of India

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