Comparing View Factor modeling frameworks for the estimation of incident solar energy

Arias-Rosales, Andrés; LeDuc, Philip R.

doi:10.1016/j.apenergy.2020.115510

Cited by 12 publications

(3 citation statements)

References 44 publications

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“…The quantification of the solar potential from good quality in situ measurements is ideal for any solar application project [12,13]. However, in the absence of these, solar radiation estimation models are used [14,15]. Theoretical and numerical models for estimating incident solar radiation have been developed in different climates for local applicability and sometimes according to climatic similarities [16].…”

Section: Introductionmentioning

confidence: 99%

Estimation of Solar Radiation and Feasibility Analysis of a Concentrating Solar Power Plant in Birao, Central African Republic

Chara-Dackou,

Njomo,

Tchinda

et al. 2023

IJHT

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This study develops numerical models to estimate the solar radiation in Birao, Central African Republic and evaluates the feasibility of a concentrating solar power (CSP) plant. Three solar radiation estimation models are assessed using statistical performance metrics. The Capderou model shows the best accuracy with mean absolute deviation of 14% and root mean square deviation of 17%. The model is applied with three sun-tracking modes, with the north-south axis mode having the lowest RMSD of 7% in estimating direct normal irradiance. A techno-economic analysis indicates that the solar resource in Birao can support a CSP plant. The developed estimation tool can help optimize the siting and sizing of CSP systems to enable greater solar energy utilization.

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Section: Introductionmentioning

confidence: 99%

Estimation of Solar Radiation and Feasibility Analysis of a Concentrating Solar Power Plant in Birao, Central African Republic

Chara-Dackou,

Njomo,

Tchinda

et al. 2023

IJHT

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“…Optimal row spacing taking into account economic factors such as land purchase and preparation and wiring costs is dealt with in [12]. Masking (expressed by sky view factor) that affects the diffuse incident radiation on collectors was considered later in time in [13][14][15]. The study in [13] emphasizes the difference in the amounts of incident diffuse radiation on a top and a bottom module installed on a collector due to the difference in the sky view factors.…”

Section: Introductionmentioning

confidence: 99%

“…Various types of view factors to the sky, between opposite collectors, between collector and shaded and unshaded grounds and for front and rear sides of collectors were developed in [14]. The work in [15] analyses the sky view factor for isotropic and anisotropic diffuse and albedo radiation. The effect of shading and masking on optimized PV system deployments is dealt with in [16] for horizontal and sloped fields.…”

Section: Introductionmentioning

confidence: 99%

Shading and Masking of PV Collectors on Horizontal and Sloped Planes Facing South and North—A Comparative Study

2021

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With the increase in PV system installations, the available free land and rooftops for these systems may become scarcer, and therefore sloped fields facing the north may be utilized for that purpose. In deployments of PV collectors in multiple rows, either on horizontal or sloped planes, the second and subsequent rows are subject to two effects: shading and masking. Both effects reduce the electric energy generated by the PV systems. Multiple rows of collectors are deployed on horizontal planes and on sloped planes facing south, and literature on the topic has been published. No literature deals analytically with deployments of PV fields on north-facing slopes in the northern hemisphere, to the best of our knowledge. The present study develops explicit analytical expressions for the shadow height and length cast on a collector row by a row in front in multiple-row PV systems installed on slopes facing north. In addition, analytical expressions are developed for row spacing and sky view factors, altogether leading consequently to the determination of shading and masking losses. Having the developed expressions, a comparison was made between PV deployments on north-facing sloped planes to PV deployments on horizontal and south-facing slopes regarding shading and masking losses. The main finding is that the percentage of masking losses (diffuse radiation) may exceed the percentage of shading losses (beam radiation) in PV fields. At the local site 32∘ N, collector inclination angle β=25∘ and sloped-plane ε=10∘, for example, the percentage of masking losses for a horizontal plane is 6.90%; for a sloped plane facing south, the losses are 5.39%, and for a sloped plane facing north, the losses are 6.86%. In comparison to the masking losses, the percentage of shading losses for the horizontal plane is 0.83%; for the sloped plane facing south, the losses are 0.42%, and for the sloped plane facing north, the losses are 1.37%.

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Direct and diffuse shading factors modelling for the most representative agrivoltaic system layouts

Zainali

Stridh

et al. 2023

Applied Energy

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Comparing View Factor modeling frameworks for the estimation of incident solar energy

Cited by 12 publications

References 44 publications

Estimation of Solar Radiation and Feasibility Analysis of a Concentrating Solar Power Plant in Birao, Central African Republic

Estimation of Solar Radiation and Feasibility Analysis of a Concentrating Solar Power Plant in Birao, Central African Republic

Shading and Masking of PV Collectors on Horizontal and Sloped Planes Facing South and North—A Comparative Study

Direct and diffuse shading factors modelling for the most representative agrivoltaic system layouts

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