Synchronisation Control Action for Very Low-Frequency Oscillations

Duggan, Connor; Brogan, Paul; Liu, Xueqin; Best, Robert; Morrow, D. John

doi:10.1109/issc52156.2021.9467843

Cited by 3 publications

(2 citation statements)

References 20 publications

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“…Previous mechanism analysis has attributed VLFOs to negatively damped governors (Chen et al, 2017), backlash (De Marco et al, 2018) and time delays (Duggan et al, 2021) within governor control systems. Several mitigation measures have been proposed to increase the damping of the VLFOs.…”

Section: Literature Reviewmentioning

confidence: 99%

Active power control from wind farms for damping very low-frequency oscillations

et al. 2022

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Timely remote activation of frequency response, provided by converter-based generation, can improve the damping of very low-frequency (VLF) oscillations. The research presented is based on both power system models and actual data from phasor measurement units (PMU) on the Irish power system. The performance of active power control (APC) is investigated, and variations in wind speed, droop, time lag and resource capacity demonstrate their effectiveness at damping wide-spectrum VLF modes. PMU data that captures the activation and deactivation of APC at wind farms is presented and analyzed; it demonstrates how APC control effectively dampens VLF modes on the Irish system. These observations are supported by sensitivity analysis carried out a power system model in DIgSILENT PowerFactory. These results demonstrate the improvement in VLF mode stability that APC can provide at wind generation. It is demonstrated that minimal amounts of generation curtailment and modest droop settings are sufficient to see substantial VLF mode damping. Index Terms—Active Power Control, Oscillation damping, Very Low-Frequency Oscillations, PMU.

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Section: Literature Reviewmentioning

confidence: 99%

Active power control from wind farms for damping very low-frequency oscillations

et al. 2022

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“…The model used in this paper to replicate the power plant gas turbine and speed governor is the GAST model, as it is one of the most used for dynamic modeling [12][13][14]. The AVR model chosen was the simplified excitation system (SEXS) [15,16] and, to represent the SG, the model used was GENSAL [17][18][19].…”

Section: Introductionmentioning

confidence: 99%

Synchronous Generator Stability Characterization for Gas Power Plants Using Load Rejection Tests

Mugarra,

Guerrero,

Mahtani

et al. 2023

Applied Sciences

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For power grid operators, knowing the transient response of the synchronous generators (SGs) included in their grids is important in order to simulate and monitor faults and other contingencies. However, the time constant of the automatic voltage regulator (AVR) and speed governors of SGs are not fast enough to show their transient dynamics in the case of a fault in the grid. This paper presents a fieldwork carried out in more than 60 gas power plants, where the response of their controllers was studied. These power plants are running and supplying electricity to the Spanish grid. The study consists of recording some SG responses in different situations, varying the AVR or the speed governor setpoints while the generator is running at no-load conditions, and also performing load rejection tests, achieving a real fault emulation. Once all the data are gathered, a fitting of the SG parameters is performed by computer simulations using GENSAL, GAST and SEXS models replicating the performed field tests. This work allows us to build an accurate network model for the whole power system and check which plants are having trouble in the case of contingencies in the grid.

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Very Low-Frequency Oscillation Source Localization on Ireland's Power System

Duggan

Liu

Brogan

et al. 2022

IEEE Open J. Ind. Applicat.

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This paper presents an approach for studying Very Low-Frequency Oscillations (VLFOs) between 0.03 and 0.08 Hz that have been observed on Irelands All-Island transmission system. Previous work by Ireland's TSO has found that the occurrence of the VLFO is linked to the generation dispatch of synchronous machines with governor control. This study verifies previous research by Ireland's TSO and analyses sensitivities such as inertia, system frequency and online generator status that causes an increase in VLF mode magnitude. This paper's results are based on 1-second resolution system frequency, metered generation and power system metric data from 1/1/2018 to 1/10/2020. This analysis demonstrates that the VLF oscillatory mode's stability is highly correlated if governors that consistently provide positive damping torque to the VLF mode are not synchronized. The findings from the study are demonstrated on several events on the Irish system using PMU data. The governor-based dissipating energy flow method is used to validate the relationships found from the generator status and system frequency case study.

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Synchronisation Control Action for Very Low-Frequency Oscillations

Cited by 3 publications

References 20 publications

Active power control from wind farms for damping very low-frequency oscillations

Active power control from wind farms for damping very low-frequency oscillations

Synchronous Generator Stability Characterization for Gas Power Plants Using Load Rejection Tests

Very Low-Frequency Oscillation Source Localization on Ireland's Power System

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