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Deriving Optimal End of Day Storage for Pumped-Storage Power Plants in the Joint Energy and Reserve Day-Ahead Scheduling

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  • Manuel Chazarra

    (Department of Hydraulic, Energy and Environment Engineering, Escuela de Ingenieros de Caminos, Canales y Puertos, Universidad Politécnica de Madrid, 28040 Madrid, Spain)

  • Juan I. Pérez-Díaz

    (Department of Hydraulic, Energy and Environment Engineering, Escuela de Ingenieros de Caminos, Canales y Puertos, Universidad Politécnica de Madrid, 28040 Madrid, Spain)

  • Javier García-González

    (Institute for Research in Technology, Technical School of Engineering (ICAI), Comillas Pontifical University, 28015 Madrid, Spain)

Abstract

This paper presents a new methodology to maximise the income and derive the optimal end of day storage of closed-loop and daily-cycle pumped-storage hydropower plants. The plants participate in the day-ahead energy market as a price-taker and in the secondary regulation reserve market as a price-maker, in the context of the Iberian electricity system. The real-time use of the committed reserves is considered in the model formulation. The operation of the plants with the proposed methodology is compared to the ones that use an end of day storage of an empty reservoir or half of the storage capacity. Results show that the proposed methodology increases the maximum theoretical income in all the plants analysed both if they only participate in the day-ahead energy market and if they also participate in the secondary regulation service. It is also shown that the increase in the maximum theoretical income strongly depends on the size of the plant. In addition, it is proven that the end of day storages change notably in the new reserve-driven strategies of pumped-storage hydropower plants and that the proposed methodology is even more recommended if the secondary regulation service is considered.

Suggested Citation

  • Manuel Chazarra & Juan I. Pérez-Díaz & Javier García-González, 2017. "Deriving Optimal End of Day Storage for Pumped-Storage Power Plants in the Joint Energy and Reserve Day-Ahead Scheduling," Energies, MDPI, vol. 10(6), pages 1-18, June.
    • Handle: RePEc:gam:jeners:v:10:y:2017:i:6:p:813-:d:101574
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    References listed on IDEAS

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    1. Graves, Frank & Jenkin, Thomas & Murphy, Dean, 1999. "Opportunities for Electricity Storage in Deregulating Markets," The Electricity Journal, Elsevier, vol. 12(8), pages 46-56, October.
    2. Connolly, D. & Lund, H. & Finn, P. & Mathiesen, B.V. & Leahy, M., 2011. "Practical operation strategies for pumped hydroelectric energy storage (PHES) utilising electricity price arbitrage," Energy Policy, Elsevier, vol. 39(7), pages 4189-4196, July.
    3. Tom Brijs & Frederik Geth & Sauleh Siddiqui & Benjamin F. Hobbs & Ronnie Belmans, 2016. "Price-Based Unit Commitment Electricity Storage Arbitrage with Piecewise Linear Price-Effects," Discussion Papers of DIW Berlin 1567, DIW Berlin, German Institute for Economic Research.
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    1. Hunt, Julian David & Zakeri, Behnam & Lopes, Rafael & Barbosa, Paulo Sérgio Franco & Nascimento, Andreas & Castro, Nivalde José de & Brandão, Roberto & Schneider, Paulo Smith & Wada, Yoshihide, 2020. "Existing and new arrangements of pumped-hydro storage plants," Renewable and Sustainable Energy Reviews, Elsevier, vol. 129(C).
    2. Chang-Gi Min & Mun-Kyeom Kim, 2017. "Flexibility-Based Reserve Scheduling of Pumped Hydroelectric Energy Storage in Korea," Energies, MDPI, vol. 10(10), pages 1-13, September.
    3. Xin Lyu & Ke Yang & Juejing Fang & Jinzhou Tang & Yu Wang, 2022. "Feasibility Study of Construction of Pumped Storage Power Station Using Abandoned Mines: A Case Study of the Shitai Mine," Energies, MDPI, vol. 16(1), pages 1-16, December.

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