Estimating a Power System’s Load Relief Factor Using the High-Resolution Data of Fault Recorders

Susanto, Julius; Shahnia, Farhad; Sharafi, Dean; Kwek, Leon

doi:10.1109/icpes47639.2019.9105658

Cited by 2 publications

(2 citation statements)

References 11 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Simplified equivalent governor model proposed in [8] where P load0 is the system load at nominal frequency in MW, k p is the static dimensionless frequency-dependant load relief factor (LRF), ∆f (t) is the frequency deviation from the nominal frequency in Hz, and f n is the nominal frequency in Hz. Given ordered pairs of frequency and system load samples measured from the onset of the contingency to the time of frequency recovery and stabilisation, the load relief factor can be readily estimated by applying a linear regression on (3) [17].…”

Section: F Part 6: Load Relief Calculationmentioning

confidence: 99%

See 1 more Smart Citation

Online Security Assessment of Low-Inertia Power Systems: A Real-Time Frequency Stability Tool for the Australian South-West Interconnected System

Fereidouni¹,

Susanto²,

Mancarella³

et al. 2020

Preprint

Self Cite

View full text Add to dashboard Cite

In small/medium-sized isolated power networks with low rotational inertia and high penetration of renewables, generation/load contingency events may cause large frequency excursions, potentially leading to cascading failures and even blackouts. Therefore, it is crucial for system operators to be able to monitor the state of the network in real-time and predict the maximum possible frequency deviations at all times.This paper presents a real-time frequency stability (RTFS) tool developed by the Australian Energy Market Operator (AEMO) and operationalized in the control room for the South West Interconnected System (SWIS) to ensure that the available spinning reserve is sufficient and fast enough to arrest frequency excursions under any conditions, and particularly low-inertia ones. To reduce the computational burden and complexity of the different turbine-governor models, a simple first-order lag function with two adjustable variables has been used for each of the generator. These adjustable parameters, along with other key model parameters such as load damping and inertia, have been calibrated against actual frequency response using high-speed fault recorder data from historical events. As demonstrated in several case studies, the real-time tool has proven to be accurate at predicting the trajectory of system frequency after credible contingencies, thus suggesting that similar implementations could be carried out elsewhere while power systems worldwide progress towards lower inertia.

show abstract

Section: F Part 6: Load Relief Calculationmentioning

confidence: 99%

“…An LRF of k p = 2 is used in the model based on a series of estimates made with high-resolution fault recorder data from previous contingency events in the SWIS [17] (see also Section. II-F).…”

Section: B Load Relief Factormentioning

confidence: 99%