Abstract

Abstract This paper introduces an effective and reliable approach based on a multi-population approach, namely the self-adaptive multi-population Jaya algorithm (SAMP-JA), to extract multi-purpose reservoir operation policies. The current research focused on two goals: minimizing irrigation deficits and maximizing hydropower generation. Three different models were formulated. The results were compared with those for an ordinary Jaya algorithm (JA), particle swarm optimization (PSO), and an invasive weed optimization (IWO) algorithm. In Model-1, the minimum irrigation deficit obtained by SAMP-JA and JA was 305092.99 . SAMP-JA was better than JA, PSO and IWO in terms of convergence. In Model-2, the maximum hydropower generation achieved by SAMP-JA, JA and PSO was 1723.50 . When comparing the average hydropower generation, SAMP-JA and PSO performed better than JA and IWO. In terms of convergence, SAMP-JA was better than PSO. In Model-3, a self-adaptive multi-population multi-objective Jaya algorithm (SAMP-MOJA) was better than multi-objective particle swarm optimization (MOPSO) and multi-objective Jaya algorithm (MOJA) in terms of maximum hydropower generation, and MOPSO was better than SAMP-MOJA and MOJA in terms of minimum irrigation deficiency. While comparing convergence, SAMP-MOJA was found to be better than MOPSO and MOJA. Overall, SAMP-JA was found to outperform JA, POS and IWO.

Highlights

  • In the case of reservoir operation problems, decisions about releases and storage over a period must be taken with regard to variability in inflows and demands in mind for the best possible system performance (Kumar & Reddy 2007)

  • The findings show that Jaya algorithm (JA) was better than particle swarm optimization (PSO)

  • The results are compared with Jaya algorithm (JA), particle swarm optimization (PSO), and Invasive weed optimization (IWO) algorithm

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Summary

Introduction

In the case of reservoir operation problems, decisions about releases and storage over a period must be taken with regard to variability in inflows and demands in mind for the best possible system performance (Kumar & Reddy 2007). The traditional optimization techniques used in reservoir operation include linear programming (LP), non-linear programming (NLP), and dynamic programming (DP). While these techniques have been used widely in the past, there have been a few restrictions (Hossain & El-shafie 2013). A model should be built as close to reality as possible to ensure the best possible performance of such a reservoir system In this process, the model is capable of solving nonlinearity and no convexity problems in its field. Traditional optimization techniques were found to be trapped in local optimal solutions and difficult to solve multi-objective, non-distinctive, non-convex and discontinuous functionalities (Reddy & Kumar 2006)

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