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Rapid Reserve Generation from a Francis Turbine for System Frequency Control

Author

Listed:
  • Dean R. Giosio

    (Australian Maritime College, University of Tasmania, Launceston 7250, Tasmania, Australia)

  • Alan D. Henderson

    (School of Engineering & ICT, University of Tasmania, Hobart 7005, Tasmania, Australia)

  • Jessica M. Walker

    (Australian Maritime College, University of Tasmania, Launceston 7250, Tasmania, Australia)

  • Paul A. Brandner

    (Australian Maritime College, University of Tasmania, Launceston 7250, Tasmania, Australia)

Abstract

The increase in contributions from non base load renewables, such as wind and solar, can have adverse effects on the stability of an electrical grid. In this study, the possibility of rapidly loading a Francis turbine from a tail water depression (TWD) mode for providing additional system frequency control is investigated. Based on the analysis of full-scale TWD test results and key findings from the transient testing of a micro-hydro scale turbine unit, a detailed description of the TWD transition process is given. The formulation of an improved turbine model for use in one-dimensional hydro-electric plant models is presented with simulation results compared to full-scale data. The analytical model, which calculates output power according to the conservation of angular momentum and identified sources of loss, is used in parallel with full-scale and model scale test observations to elucidate the events and mechanisms occurring during this proposed transition. The output response, in terms of active power, was found to be highly dependent on guide vane opening rate in both full-scale and model tests. For an approximate doubling in opening rate, the duration of the reverse power flow was reduced by 38% and 21%, for full-scale and model units, while the low pressure transient increased by 16% and 8%, respectively. The analytical model was shown to capture the general response characteristic in all cases tested; however, output power response was over predicted due to two identified model assumptions made, while, for the more rapid opening, the penstock pressure was under predicted by approximately 15%.

Suggested Citation

  • Dean R. Giosio & Alan D. Henderson & Jessica M. Walker & Paul A. Brandner, 2017. "Rapid Reserve Generation from a Francis Turbine for System Frequency Control," Energies, MDPI, vol. 10(4), pages 1-15, April.
    • Handle: RePEc:gam:jeners:v:10:y:2017:i:4:p:496-:d:95225
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    References listed on IDEAS

    as
    1. Giosio, D.R. & Henderson, A.D. & Walker, J.M. & Brandner, P.A. & Sargison, J.E. & Gautam, P., 2015. "Design and performance evaluation of a pump-as-turbine micro-hydro test facility with incorporated inlet flow control," Renewable Energy, Elsevier, vol. 78(C), pages 1-6.
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    Cited by:

    1. Andrey Achitaev & Pavel Ilyushin & Konstantin Suslov & Sergey Kobyletski, 2022. "Dynamic Simulation of Starting and Emergency Conditions of a Hydraulic Unit Based on a Francis Turbine," Energies, MDPI, vol. 15(21), pages 1-18, October.
    2. Li, Huanhuan & Xu, Beibei & Riasi, Alireza & Szulc, Przemyslaw & Chen, Diyi & M'zoughi, Fares & Skjelbred, Hans Ivar & Kong, Jiehong & Tazraei, Pedram, 2019. "Performance evaluation in enabling safety for a hydropower generation system," Renewable Energy, Elsevier, vol. 143(C), pages 1628-1642.
    3. Keyun Zhuang & Chaodan Gao & Ze Li & Donglin Yan & Xiangqian Fu, 2018. "Dynamic Analyses of the Hydro-Turbine Generator Shafting System Considering the Hydraulic Instability," Energies, MDPI, vol. 11(10), pages 1-19, October.
    4. Donglin Yan & Weiyu Wang & Qijuan Chen, 2018. "Nonlinear Modeling and Dynamic Analyses of the Hydro–Turbine Governing System in the Load Shedding Transient Regime," Energies, MDPI, vol. 11(5), pages 1-17, May.
    5. Keyun Zhuang & Shehua Huang & Xiangqian Fu & Li Chen, 2022. "Nonlinear Hydraulic Vibration Modeling and Dynamic Analysis of Hydro-Turbine Generator Unit with Multiple Faults," Energies, MDPI, vol. 15(9), pages 1-23, May.

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