This morning the AEMC has published its final rule focused on clarifying how Semi-Scheduled generators should follow dispatch targets – including in dispatch intervals where prices are negative, and some had been unexpectedly switching off.
On 25th November, guest author Allan O’Neil examined the ‘X5 Constraint’. Two weeks of operation have passed, so now Allan reviews some of what’s happened.
This is the second of a short series of video snippets extracted from the 17th September 2020 presentation by Marcelle Gannon and Jonathon Dyson for the Clean Energy Council entitled ‘Maximising Profitability in the NEM’ for Wind Farms.
Today (Thu 19th Nov 2020) the AEMC published a draft ruling following the AER request for a rule change relating to Semi-Scheduled generators … which itself followed from two COAG Energy Council requests to them
Following the consultation process conducted by the AER (stemming from their Issues Paper 3 months ago) the AER has today submitted a rule change request to the AEMC relating to Semi-Scheduled generation.
Prompted by the recent AER Issues Paper (submissions on that due today – Friday 24th July) but also aware that I’ve not yet published some broader thoughts in response to the ESB’s requests for input into their Discussion Paper on the Two Sided Market concept, I’ve posted some further thoughts. These have been informed by a longitudinal analysis of Aggregate ‘Raw Off-target’ values across all Semi-Scheduled plant.
Marcelle digs into the data to find out what the real issues are in the AER’s proposed rule change for semi-scheduled generators.
Here’s an attempt to translate the concern underlying the AER Issues Paper into ‘plain English’ via the popular song.
It’s not a surprise to me to see that someone (the AER in this case) has released an Issues Paper canvassing options for changing the way Semi-Scheduled generators interact with the dispatch process. Not a surprise, as our prior analysis suggests the current approach is not sustainable or scalable.
Recent invitations (from COAG Energy Council and AEMO) prompt some further analysis of the data set assembled for the GSD2019 in order to understand more about one of the challenges in balancing Supply and Demand in the NEM 2.0 world.
Third case study in a growing series – on this occasion looking at the (extreme – and possibly excessive?) lengths taken by Tailem Bend Solar Farm to avoid being dispatched at times of negative spot prices in South Australia. This analysis is specifically focused on Wednesday 6th November 2019.
Thursday 10th October 2019 presented another day of many negative price events in the QLD region. In this Case Study (prepared for dual purposes) we look at how one particular solar farm operated through this period – Ross River Solar Farm.
A detailed look at two specific trading periods in the day (Tuesday 24th July 2018) that saw negative dispatch prices occur at the start of trading periods – hence provided a case study for how existing Semi-Scheduled plant respond (especially in combination with transmission constraints and the Semi-Dispatch Cap).
An article that sums up some decidedly un-quick calculations we’ve performed – looking over an 8 week period to 13th September to estimate how much wind power has been curtailed by the AEMO.
A quick note about high wind speeds in South Australia this afternoon leading to AEMO constraining wind farm output down for System Strength reasons.