Scarce use of aggregate dispatch conformance to-date
No Mixed aggregate dispatch groups have been registered.
No Mixed aggregate dispatch groups have been registered.
No sooner had we noted that ‘AEMO changes mind, and directs Murray instead (to run as syncon) for System Strength in Victoria on Wednesday 15th October 2025’ then we receive MN129618 at 09:00 that helps...
Less than an hour after directing Jeeralang (for System Strength in Victoria), AEMO changes its mind and directs Murray instead. Though this was also short-lived!
As AEMO had telegraphed yesterday, just after 08:00 (NEM time) on Wednesday 15th October 2025, the AEMO issued Directions to various units at EnergyAustralia’s Jeeralang Power Station for System Strength in Victoria.
In the final part of our four-part CIS series, we zoom out to examine what government-backed Contract-for-Difference schemes are really achieving — drawing on policy lessons from the Nelson Review.
Worth noting two market notices today flagging possible intervention because of System Strength issues in Victoria tomorrow (Wednesday 15th October 2025).
It appears that there was some large(ish) trip in demand somewhere on the Queensland network, given the spike in frequency at ~07:28 on Tuesday 14th October 2025.
A short note to record a large-size drop in ‘Market Demand’ in the Queensland region on Tuesday morning 14th October 2025, as captured in this ez2view ‘Notification’ widget alert at 07:31 (NEM time).
Given that we’ve written about that outage several times before, worth noting that Eraring Unit 3 came back online Sunday evening 12th October 2025.
There was a short-lived (but interesting) price spike for ENERGY in the NSW region on Friday evening 10th October 2025. Here's a first look.
In this guest article, Matt Grover from Fluence draws on operational data and real-world trading experience to unpack how Australia’s grid-scale batteries performed across three June 2025 peak days — and what capabilities belong...
With the Queensland state government’s new energy roadmap due out tomorrow, Greg Elkins highlights how distorted signals and state interventions expose a new NEM failure.
A sequence of afternoon intervals stand out because the forecast appeared to be biased low – self-forecasts suddenly dropped roughly 30-40 percentage points and then increased a short time later.
Theoretically, if a self-forecasting system never offers forecasts for more than 60% of intervals it may perpetually skip the performance assessment and the system could continue for use unsuppressed.
In another style of biasing a self-forecast, "lunar megawatts" represent an expectation of solar farm generation at night when it really should be zero.
The forecast differences would contribute to improved lower RMSE and MAE scores, relative to AWEFS_ASEFS, in the weekly performance assessment.
In today’s article (part 1 in this series) we present an example of biasing (at an unnamed solar farm), which we find aligns with FCAS cost mitigation.
47% of dispatch intervals for semi-scheduled solar units are seeing a self-forecast used. When there are gaps, was the unit suppressed?
Dan dives into the history of the NEM’s market cap and explores how high-end prices contribute to regional settlement costs and cap payouts.
We summarise how wind units are using self-forecasting to-date. The analysis leads us to consider where upcoming market change may lead the industry.