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On the Implementation of Variable Speed in Pump-Turbine Units Providing Primary and Secondary Load-Frequency Control in Generating Mode

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  • José Ignacio Sarasúa

    (Department of Hydraulic, Energy and Environmental Engineering, School of Civil Engineering, Technical University of Madrid, C/Profesor Aranguren, Madrid 28040, Spain
    These authors contributed equally to this work.)

  • Juan Ignacio Pérez-Díaz

    (Department of Hydraulic, Energy and Environmental Engineering, School of Civil Engineering, Technical University of Madrid, C/Profesor Aranguren, Madrid 28040, Spain
    These authors contributed equally to this work.)

  • Blanca Torres Vara

    (Department of Hydraulic, Energy and Environmental Engineering, School of Civil Engineering, Technical University of Madrid, C/Profesor Aranguren, Madrid 28040, Spain)

Abstract

This paper analyses different control strategies for the speed control loop of a variable-speed pump-turbine unit equipped with a doubly fed induction generator, operating in generating mode in an isolated power system with high penetration of intermittent renewable energy. The control strategies are evaluated and compared to each other in terms of the amount of water discharged through the pump-turbine and of the wicket gates fatigue while providing primary and secondary load-frequency control. The influence of the penstock length and the initial operating point on the performance of each control strategy is studied in detail. For these purposes, several simulations have been performed with a suitable dynamic model of the pumped-storage hydropower plant and the power system. The results of the paper indicate that a proper control strategy would consist in updating the reference speed according to the power generation schedule and keeping it constant within each scheduling period (typically 1 h).

Suggested Citation

  • José Ignacio Sarasúa & Juan Ignacio Pérez-Díaz & Blanca Torres Vara, 2015. "On the Implementation of Variable Speed in Pump-Turbine Units Providing Primary and Secondary Load-Frequency Control in Generating Mode," Energies, MDPI, vol. 8(12), pages 1-17, December.
    • Handle: RePEc:gam:jeners:v:8:y:2015:i:12:p:12382-13575:d:59677
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    References listed on IDEAS

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    1. Anagnostopoulos, J.S. & Papantonis, D.E., 2008. "Simulation and size optimization of a pumped–storage power plant for the recovery of wind-farms rejected energy," Renewable Energy, Elsevier, vol. 33(7), pages 1685-1694.
    2. Ma, Tao & Yang, Hongxing & Lu, Lin & Peng, Jinqing, 2014. "Technical feasibility study on a standalone hybrid solar-wind system with pumped hydro storage for a remote island in Hong Kong," Renewable Energy, Elsevier, vol. 69(C), pages 7-15.
    3. Kaldellis, J. K. & Kavadias, K. A., 2001. "Optimal wind-hydro solution for Aegean Sea islands' electricity-demand fulfilment," Applied Energy, Elsevier, vol. 70(4), pages 333-354, December.
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    Cited by:

    1. Yang, Weijia & Yang, Jiandong, 2019. "Advantage of variable-speed pumped storage plants for mitigating wind power variations: Integrated modelling and performance assessment," Applied Energy, Elsevier, vol. 237(C), pages 720-732.
    2. Vasudevan, Krishnakumar R. & Ramachandaramurthy, Vigna K. & Venugopal, Gomathi & Ekanayake, J.B. & Tiong, S.K., 2021. "Variable speed pumped hydro storage: A review of converters, controls and energy management strategies," Renewable and Sustainable Energy Reviews, Elsevier, vol. 135(C).

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