Abstract

Probabilistic solar forecasting is an issue of growing relevance for the integration of photovoltaic (PV) energy. However, for short-term applications, estimating the forecast uncertainty is challenging and usually delegated to statistical models. To address this limitation, the present work proposes an approach which combines physical and statistical foundations and leverages on satellite-derived clear-sky index (kc) and cloud motion vectors (CMV), both traditionally used for deterministic forecasting. The forecast uncertainty is estimated by using the CMV in a different way than the one generally used by standard CMV-based forecasting approach and by implementing an ensemble approach based on a Gaussian noise-adding step to both the kc and the CMV estimations. Using 15-min average ground-measured Global Horizontal Irradiance (GHI) data for two locations in France as reference, the proposed model shows to largely surpass the baseline probabilistic forecast Complete History Persistence Ensemble (CH-PeEn), reducing the Continuous Ranked Probability Score (CRPS) between 37% and 62%, depending on the forecast horizon. Results also show that this is mainly driven by improving the model’s sharpness, which was measured using the Prediction Interval Normalized Average Width (PINAW) metric.

Highlights

  • The satellite-derived data used are time-series of Global Horizontal Irradiance (GHI) maps with a native time step of 15 min and a spatial resolution of approximately 3 × 4.5 km. This satellite dataset has been extracted from the database HelioClim-3 version 5, based on the Heliosat-2 method applied on images from the sensor SEVIRI of Meteosat Second Generation (0◦ Service)

  • The ground-based measurements of GHI used as reference are first quality-checked at their native time resolution: 1-min and 5-min time steps, respectively, for Carpentras and Signes

  • This quality check first uses an automatic procedure based on upper and lower limits for extremely rare intervals, as described by Reference [55], and on a visual inspection. These time-series of GHI are averaged to 15-min to be consistent with the satellite data acquired every 15-min

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Summary

Introduction

Publisher’s Note: MDPI stays neutral with regard to jurisdictional claims in published maps and institutional affiliations. The effect of the variability of renewable power production increases with the growing penetration of photovoltaic (PV) generations. This raises challenges to power systems operators, increasing their operational costs [1]. PV power generation forecasting has become an active field of research to mitigate the effects of this variability [2]

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