Very Fast FCAS, because it operates at a faster timescale, can arrest the rise or fall in frequency more rapidly than the current fast service and therefore provides an avenue to mitigate the costs of needing to procure increasing levels of the existing fast service. The markets (raise and lower) are going live on 9 October 2023.
Spot price volatility was experienced in Queensland and New South Wales on 4th September 2023.
A week’s worth of data provides indications of how semi-scheduled generators are using bid MaxAvail to manage dispatch availability.
It is indispensable to understand how the semi-scheduled unit availability gets produced to optimally manage the critical inputs and comprehend dispatch outcomes. This article explains the key inputs and processes, focusing on the dispatch timeframe.
The change to use MaxAvail from the energy bid, for semi-scheduled units, was implemented on 7 August 2023.
Don’t forget about FCAS when the energy market starts to steal the spotlight.
Light winds and a constrained interconnector contributed to elevated prices on 1 August 2023.
AEMO is re-enabling the ‘MaxAvail’ figure in bids for Semi-Scheduled units. It will act as a limit on capacity available, feeding into the NEMDE dispatch process for the unit. We look at how Semi-Scheduled plant have currently been treating MaxAvail in the bid and share some insights.
A quick note to show the last dispatch interval of output from Lidell Unit 4, with the two remaining units slated to follow suit in the coming days.
We delve deeper into dispatch availability self-forecasts and the assessment process to further enhance our understanding of this important aspect, testing sensitivity to gate closure times and requirements on minimum intervals.
Estimated RERT costs published, pushing past the market price cap for dispatched volumes.
The forecast for Friday (3 February 2023) evening’s demand was that a new all-time maximum would occur and a lack of reserve was expected. To maintain the grid in a reliable operating state AEMO signaled to the market that the…
A successful return to service for the Waddamana to Palmerston 220 kV lines following damage sustained during landslides on 14 October 2022.
In this article we explore the impacts on wind power generation as the storms passed through, in the leadup to the transmission line trip at 16:39 (NEM time, reflected in the market by the 16:45 interval) on 12 November 2022.
Casting a look over wholesale demand response in the NEM, one year on, how has participation grown and the capability been used?
The market volatility on Wednesday 10th August 2022 turned out to be illusive. We review unit output by fuel type to study how different generator groups responded on the day (in aggregate) finding increases, decreases and patterns in between.
In this article we look more closely at 1st and 2nd February 2022 – and particularly at where and when the changes in rooftop PV occurred, narrowing our assessment to south-east Queensland regions. It follows on from Part A which inspected how Queensland rooftop PV output varied at the state level.
Widespread and heavy rainfall occurred across southeast Queensland during the week ending Sunday 27th February, 2022. The deluge produced some of the highest rainfall totals on record and extensive flooding. Did electricity demand drop in association with network outages?
This article – Part A of a 2 part series – reviews how rooftop PV output varied and considers its influence on Queensland demand on the 1st and 2nd of February, 2022.
Recent WDR activity on January 31 took advantage of the spicy Victorian wholesale energy prices that eventuated in the late afternoon and early evening under unusual circumstances.