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A game theoretic model for generation capacity adequacy in electricity markets: A comparison between investment incentive mechanisms

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  • Haikel Khalfallah

    (GATE Lyon Saint-Étienne - Groupe d'Analyse et de Théorie Economique Lyon - Saint-Etienne - ENS de Lyon - École normale supérieure de Lyon - UL2 - Université Lumière - Lyon 2 - UCBL - Université Claude Bernard Lyon 1 - Université de Lyon - UJM - Université Jean Monnet - Saint-Étienne - CNRS - Centre National de la Recherche Scientifique)

Abstract

In this paper we study the problem of long-term capacity adequacy in electricity markets. We implement a dynamic model in which operators compete for investment and electricity production under imperfect Cournot competition. The main aim of this work is tocompare three investment incentive mechanisms: reliability options, forward capacity market - which are both market-based - and capacity payments. Apart from the oligopoly case, we also analyze collusion and monopoly cases. Stochastic dynamic programming is used to deal with the stochastic environment of the market (future demand) and mixed complementarityproblem formulation is employed to find a solution to this game. The main finding of this study is that market-based mechanisms would be the most cost-efficient mechanism for assuring long-term system adequacy and encouraging earlier and adequate new investments in the system. Moreover, generators would exert market power when introducing capacity payments. Finally, compared with a Cournot oligopoly, collusion and monopolistic situations lead to more installed capacities with market-based mechanisms and increase end-users' payments.

Suggested Citation

  • Haikel Khalfallah, 2009. "A game theoretic model for generation capacity adequacy in electricity markets: A comparison between investment incentive mechanisms," Post-Print halshs-00371842, HAL.
    • Handle: RePEc:hal:journl:halshs-00371842
    Note: View the original document on HAL open archive server: https://shs.hal.science/halshs-00371842
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    References listed on IDEAS

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    1. Pierre-Olivier Pineau & Pauli Murto, 2003. "An Oligopolistic Investment Model of the Finnish Electricity Market," Annals of Operations Research, Springer, vol. 121(1), pages 123-148, July.
    2. Steven A. Gabriel & Supat Kiet & Jifang Zhuang, 2005. "A Mixed Complementarity-Based Equilibrium Model of Natural Gas Markets," Operations Research, INFORMS, vol. 53(5), pages 799-818, October.
    3. Ford, Andrew, 1999. "Cycles in competitive electricity markets: a simulation study of the western United States," Energy Policy, Elsevier, vol. 27(11), pages 637-658, October.
    4. Frederic H. Murphy & Yves Smeers, 2005. "Generation Capacity Expansion in Imperfectly Competitive Restructured Electricity Markets," Operations Research, INFORMS, vol. 53(4), pages 646-661, August.
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    Cited by:

    1. Lynch, Muireann Á. & Nolan, Sheila & Devine, Mel T. & O’Malley, Mark, 2019. "The impacts of demand response participation in capacity markets," Applied Energy, Elsevier, vol. 250(C), pages 444-451.
    2. Nolan, Sheila & Devine, Mel & Lynch, Muireann A. & O’Malley, Mark, 2017. "The effect of Demand Response and wind generation on electricity investment and operation," Papers WP577, Economic and Social Research Institute (ESRI).
    3. Nolan, Sheila & Devine, Mel & Lynch, Muireann & O'Malley, Mark, 2016. "Impact of Demand Response Participation in Energy, Reserve and Capacity Markets," MPRA Paper 74672, University Library of Munich, Germany.

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    Keywords

    Electricity markets; capacity adequacy; dynamic programming; Nash-Cournot model; mixed complementarity problem;
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