Monitoring a photovoltaic system during the partial solar eclipse of August 2017

Kurinec, Santosh; Kucer, Michal; Schlein, Bill

doi:10.1051/epjpv/2018005

Cited by 9 publications

(6 citation statements)

References 14 publications

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“…In this event, the solar disc was 68% covered and the maximum registered decrease in electric production was 69% with respect to no eclipse conditions. A similar finding was presented by Kurinec et al [16] for a partial solar eclipse in Rochester, the United States, in 2017, in which, for a 70% partial eclipse, a maximum drop of 80% in energy production was measured; however, in this instance, a clouded sky also contributed to this decrease.…”

Section: Introductionsupporting

confidence: 87%

“…Across this wide area, both total and partial eclipses will occur, for which the model ought to be independent of the type of eclipse and the specific geometric dynamics between the Sun's and Moon's disk as viewed from different locations. From [11], it can be seen that the eclipse occultation dynamics follow a Gaussian profile that is truncated in the case of a total solar eclipse, a fact also observed in [16]. Considering that some models, such as [11], rely on assumptions regarding the motion of the Moon and Sun (i.e., linear trajectories), it is likely that, when implementing such models over wide geographical regions,…”

Section: Solar Disk Occultation Modelingmentioning

confidence: 88%

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Analyzing Regional and Local Changes in Irradiance during the 2019 Total Solar Eclipse in Chile, Using Field Observations and Analytical Modeling

2021

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Solar eclipses are astronomic phenomena in which the Earth’s moon transits between the planet and the Sun, projecting a shadow onto the planet’s surface. As solar power installed capacity increases, detailed studies of this region-wide phenomenon’s effect in irradiance is of interest; however, the literature mainly reports its effects on localized scales. A measurement campaign spanning over 1400 km was pursued for the 2 July 2019 total solar eclipse in Chile, to register the event and establish a modeling framework to assess solar eclipse effects in irradiance over wide regional scales. This work describes the event and presents an estimation framework to decompose atmospheric and eclipse effects on irradiance. An analytical model was applied to study irradiance attenuation throughout the Chilean mainland territory, using satellite-derived and astronomical data as inputs compared to ground measurements in eight stations. Results showed good agreement between model and observations, with Mean Bias Errors of −0.008 to 0.98 W/m2 for Global Horizontal Irradiance and −0.004 to −4.664 W/m2 for Direct Normal Irradiance, with Normalized Root Mean Squared Errors of 0.7–5.8% and 1.4–12.2%, respectively. Energy losses due to obscuration corresponded between 20–40% for Global Horizontal Irradiance and 25–50% for Direct Normal Irradiance over Chilean territory.

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Section: Introductionsupporting

confidence: 87%

Section: Solar Disk Occultation Modelingmentioning

confidence: 88%

Analyzing Regional and Local Changes in Irradiance during the 2019 Total Solar Eclipse in Chile, Using Field Observations and Analytical Modeling

2021

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“…Studies have been conducted to determine the overall behaviour of PV systems during an eclipse. A study monitored the performance of a 4.85 kW PV system during the 21 August 2017 eclipse and estimated the performance measurements using irradiance calculation approaches [12]. However, it does not quantify the performance of the system using one of the standard accepted metrics such as performance ratio (PR), energy performance index, or PPI as recognised by the industry [13][14][15][16].…”

Section: Related Workmentioning

confidence: 99%

“…The impact of the eclipse on the switching of the capacitor banks can also be quantified within the period of interest. Capacitor bank switching constraints and reactive power injection is as given in (12) and (13), respectively [49,50] (13) where N Daily Cap Switching is the total number of switching steps by the switched capacitor in a day, N Cap Switching, t is the number of switching operations at a time interval t, N Cap Switching max is the maximum total number of capacitor switching operations per day, Q cb max n is the maximum allowable reactive power injection by a capacitor bank and Q cb n is the actual reactive power injection by the capacitor bank.…”

Section: Voltage Device Operation Analysis At the Feedersmentioning

confidence: 99%

Case study on the effects of partial solar eclipse on distributed PV systems and management areas

Sundararajan¹,

Olowu²,

Wei³

et al. 2019

IET Smart Grid

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Photovoltaic (PV) systems depend on irradiance, ambient temperature and module temperature. A solar eclipse causes significant changes in these parameters, thereby impacting PV generation profile, performance, and power quality of larger grid where they connect to. This paper presents a case study to evaluate the impacts of the solar eclipse of August 21, 2017 on two real-world grid-tied PV systems (1.4MW and 355kW) in Miami and Daytona, Florida, the feeders they are connected to, and the management areas they belong to. Four types of analyses are conducted to obtain a comprehensive picture of the impacts using 1-minute PV generation data, hourly weather data, real feeder parameters, and daily reliability data. These analyses include: individual PV system performance measurement using power performance index; power quality analysis at the point of interconnection; a study on the operation of voltage regulating devices on the feeders during eclipse peak using an IEEE 8500 test case distribution feeder; and reliability study involving a multilayer perceptron framework for forecasting system reliability of the management areas. Results from this study provide a unique insight into how solar eclipses impact the behavior of PV systems and the grid, which would be of concern to electric utilities in future high penetration scenarios.

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“…A recent work examines the different performance indicators of PV systems [7]. A study monitored the performance of a 4.85 kW PV system during 21 August 2017 eclipse and estimated the performance measurements using irradiance calculation approaches [19]. However, it does not quantify the performance of the system using one of the standard accepted metrics such as PR that is recognised and/or applied by the industry [20][21][22][23].…”

Section: Introductionmentioning

confidence: 99%

Hybrid data‐model method to improve generation estimation and performance assessment of grid‐tied PV: a case study

Sundararajan¹,

Sarwat²

2019

IET Renewable Power Generation

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Increased installed capacity of distributed photovoltaic (PV) systems has necessitated accurate measurement and tracking of PV performance under locality-specific conditions of irradiance, temperature, and derate factors. Existing PV generation estimation methods are strictly model based and not responsive to changes in weather and system losses. Metrics computed using these methods, therefore, do not capture the real PV behaviour well. This study proposes a hybrid data-model method (HDMM) that uses historical PV data in addition to model information to improve the accuracy of generation estimation. The generation estimated by HDMM is used to compute performance metrics-performance ratio, yield, capacity factor, energy performance index, and power performance index-for two real-world PV systems at Miami (ℳ, 1.4 MW) and Daytona (D, 1.28 MW) for 2017. The significance of these metrics is then evaluated, and a preliminary analysis of inverter efficiencies is provided. Results from this study show that when compared with the existing estimation method, HDMM performs better on an average by 75% for D and 10% for ℳ. Further, at a given point in time, system ℳ is likely to perform better than D. The study gives system installers and other stakeholders better PV system visibility, enabling aggregation and transactive energy. 2 Related work The performance of PV systems has been studied well in the literature, both at system level and module level [9, 10]. However, only system-level performance is of scope in this paper. In a prior work of the authors [11], an in-depth analysis of PV performance for a special case of the partial solar eclipse of 21 August 2017 was conducted to demonstrate how critical the problem of PV performance analysis is for operators under high penetration scenarios. A study with a similar scope was conducted in [12] for

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Monitoring a photovoltaic system during the partial solar eclipse of August 2017

Cited by 9 publications

References 14 publications

Analyzing Regional and Local Changes in Irradiance during the 2019 Total Solar Eclipse in Chile, Using Field Observations and Analytical Modeling

Analyzing Regional and Local Changes in Irradiance during the 2019 Total Solar Eclipse in Chile, Using Field Observations and Analytical Modeling

Case study on the effects of partial solar eclipse on distributed PV systems and management areas

Hybrid data‐model method to improve generation estimation and performance assessment of grid‐tied PV: a case study

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