Following from the release of GenInsights21, in this article we look at some of what that analytical publication can help us understand, in terms of how the changing market is impacting on the role that renewables will increasingly play in the NEM in the years to come.
A second ‘mystery DUID’ puzzle … perhaps more complex than the first … from GenInsights21, for those who like to be challenged in ways like these.
Following from the ESB’s Final Advice, and inspired by the one year anniversary of publications the MT PASA DUID Availability data sets by AEMO (thanks to the ERM-sponsored rule change) we take a quick look about both initiatives might mean for each other. More to come in GenInsights21, time permitting.
Returning to the price spike in NSW on Wednesday morning (to $15,100/MWh for 3 dispatch intervals) to explore some of the reasons why it happened – and why it happened unexpectedly.
Day-ahead demand forecasts will be integral to any future ‘Ahead Market’. We take a look at the current state and accuracy trend of demand forecasts made 24 hours ahead as part of the broader piece of work to feed into GenInsights21.
A short article, flagging three potential tripwires we’d like to ensure NEM participants and other stakeholders are aware of in the lead-up to two significant market changes from October 2021.
Considering the extraordinary weather, bushfires, and a couple of large Victorian generators still not back from long term repairs, last week was probably less eventful for the NEM than might have been expected, but it certainly wasn’t incident-free. A very…
A first look back at yesterday (Friday 20th December 2019) in the Victorian region – where we saw extreme temperatures, high demand across VIC and SA and (perhaps because of high temperatures) a large discrepancy open up between forecast Wind Availability and actual. This would have contributed to the surprise LOR2 announcement and commencement of RERT negotiations.
Four weeks ago, we observed a significant discrepancy between AEMO’s forecast for (what would have been) a record low point for Scheduled Demand in South Australia and what actually eventuated. We’ve now had time to explore further…
AEMO’s demand forecasts for Saturday 6th January 2017 were about 500MW below what the mark turned out to be. It appears that this is due (at least in part) due to difficulties in forecasting intermittent generation which acts to reduce “Scheduled Demand”.
Today (Wednesday 27th December) sees some wild gyrations in aggregate wind farm output across South Australia. The (current) impossibility in forecasting these gyrations accurately is one of the factors contributing to higher prices seen today in South Australia and Victoria.
With high temperatures forecast for SA (hence higher demand) coinciding with low wind, social media references to “blackout” increase. Is this helpful?
Some thoughts by our guest author, about possible reasons why Engie did not bid full output of Pelican Point power station into AEMO on Wednesday 8th February (i.e. the time at which load shedding eventuated).
Demand forecast down slightly on this morning, but still looking like a record.
Here’s an update on the situation in NSW
A look at the supply/demand fundamentals in South Australia and explaining why load shedding was initiated.
Putting another cat amongst the pigeons, energy sector unions at Loy Yang A have announced Industrial Action at the station over Christmas.
After an AEMO notice of Low Reserve Condition this summer and next in the south, I had a quick look…