Reproducing oscillatory behaviour of a hydroelectric power station by computer simulation

Mansoor, Sumreena; Jones, D.; Bradley, David; Aris, F. C.; Jones, G. R.

doi:10.1016/s0967-0661(00)00068-x

Cited by 74 publications

(59 citation statements)

References 9 publications

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Section: Introductionmentioning

confidence: 99%

“…However, operation in a modified SC mode may also enable very rapid machine start-up [9][10][11]. Indeed, one of the primary roles of the Dinorwig pumped-storage hydro-electric power plant is to regulate system frequency of the British national grid, with the 317 MW units operating as spinning reserve able to be brought from zero to full power output in 10-15 s [10,11]. Magsaysay et al [9] describes the transition process from synchronous condenser mode to generation mode in which the air in the chamber is first evacuated, presumably through a relief valve, causing the tail water to rise and consequentially impinge on the turbine runner.…”

Section: Introductionmentioning

confidence: 99%

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Rapid Reserve Generation from a Francis Turbine for System Frequency Control

et al. 2017

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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%.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Rapid Reserve Generation from a Francis Turbine for System Frequency Control

et al. 2017

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“…Simulation models help gain insight into the dynamic response of a hydropower plant and to better understand the physical phenomena involved in the plant's dynamic behavior [8]. Hydropower plant's simulation models have been used for different purposes in the technical literature.…”

Section: Introductionmentioning

confidence: 99%

“…In [11], a simulation model was used for the design of the control algorithms of a new hydropower plant. In [8], a simulation model was developed to analyze the cause of an unexpected oscillatory behavior in the power output of a pumped-storage power plant.…”

Section: Introductionmentioning

confidence: 99%

Failures during Load-Frequency Control Maneuvers in an Upgraded Hydropower Plant: Causes, Identification of Causes and Solution Proposals

Pérez‐Díaz

Moreno

2015

Energies

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Abstract:The objective of this paper is to investigate the cause of several unexpected high amplitude oscillations that occurred in the surge tank water level of a real hydropower plant during secondary load-frequency control (LFC) maneuvers, after the replacement of the turbine runner, and to propose solutions that allow the power plant to continue providing secondary LFC in a safe and reliable manner. For this purpose, a simulation model has been developed and calibrated from data gathered during several on-site tests. Two different solutions are proposed in order to cope with the observed problem: using a state-dependent load change rate limiter or modifying the hydro turbine governor gains; the turbine governor remains the same as before the runner replacement. The proposed solutions are tested against a set of realistic secondary LFC signals by means of simulations and compared to each other as a function of the probability that the surge tank water level descends below a minimum safe level and the quality of the secondary LFC response. The results presented in the paper demonstrate the validity of the methodology proposed to determine the state-dependent ramp limit, as well as its effectiveness to prevent the surge tank drawdown and to provide clear insight into the trade-off between response quality and power plant safety.

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“…These models can be used during commissioning of new hydropower plants or for tuning and implementation of new control systems, among other applications (Mansoor et al, 2000).…”

Section: Introductionmentioning

confidence: 99%