On Wednesday 31st May 2023 we released our* GenInsights Quarterly Update for Q1 2023, as the fourth update in this expanding series that builds from GenInsights21 – and provided access to those clients who had pre-ordered:
As noted in the release note the report has grown by another 25% in terms of page numbers (up to 258 pages), including a significant expansion to Appendix 6.
Like the prior quarterly updates, this is available to subscribers (as an integrated PDF) at the following address:
The report contains:
(1) An Executive Summary including some Key Observations; and
(2) Six appendices which each explore different aspects of the energy transition through the detailed analysis of historical data.
These 7 components are explained more below:
|.||About this Component|
|The Executive Summary includes some x Key Observations that have been gleaned from what has been observed through the evolution of Q1 2023. These Key Observations follow in the vein of:
1) the 22 x Key Observations included in GenInsights21, and
2) the 14 x Key Themes in the earlier GRC2018.
In this appendix we take a look at a number of different ‘heartbeat’ metrics that help to identify the overall health of the NEM, including:
1) Weather factors (like temperature)
3) System inertia
With GVSC we’ve been analysing system inertia as far back as in the GRC2018, as highlighted with this article of August 2019.
More recently the AEMO has been publishing its own derivation … which allows us (in the Q4 2022 Update) to begin highlighting how the two different measures compare:
4) Frequency Performance, which is topical given exploration by others, such as Allan O’Neil in February 2023.
With respect to the Q3 update, one small snippet of the content of that Update was shared with WattClarity readers on 6th November 2022 in the article ‘Long-range trend of Instantaneous Reserve Plant Margin (IRPM) and focus on Q3 2022 – from GenInsights Quarterly’.
As discussed in Appendix 1 for the Q4 Update, what a different quarter this one was!
… + others.
|The changing shape of Grid Demand
In this appendix we take a look at the changing nature of Grid Demand, which necessitates looking into:
1) Different shapes of demand:
(a) Starting with ‘Grid Demand’
(b) But then also analysing Rooftop PV shapes to also assess ‘Underlying Demand’.
2) Continuing from the Q4 Update, we’re also including analysis of the forecastability of ‘Operational Demand’
|Wind and Large Solar
In this appendix we take a look at different aspects of the performance of Wind and Large Solar assets (separately and together), including:
2) Commercial Performance
(a) On 24th June 2023 we shared ‘Increasing curtailment of Wind and Solar across the NEM’ based on results presented earlier in the Quarterly Update for Q1 2023.
(a) The Q4 Update was topical, given AEMO upgraded its AWEFS and ASEFS forecasting systems on 23rd November 2022.
(b) The Q1 Update was topical, given the end of the ‘Grace Period’ during the quarter, as discussed by Linton on 14th April in ‘Delving deeper into dispatch availability self-forecasting performance’.
5) ‘Forecast Convergence‘ for aggregate VRE Capability
(a) how accurate are the AEMO’s forecasts of Wind + Large Solar capability across the NEM, 24 hours from the point of dispatch?
(b) given the growing installed capacity, with more Wind and Solar Farms being developed, to what extent is this challenge growing?
6) Aggregate Raw Off-Target
(a) In these Quarterly Updates, we continue to watch what’s happening in terms of collective deviation from Target across all the Wind and Solar Farms – updating and extending the analysis covered in WattClarity articles to 2020.
(b) Following the Q4 Update, Paul wrote about ‘Some revelations in GenInsights Q4 2022 about Aggregate Raw Off-Target for Semi-Scheduled units’.
+ more to come.
In this appendix we take a look at different aspects of the performance of (fully) Scheduled assets (at various levels of bundling), including:
1) Performance specifically through Q4
2) Aggregate Scheduled Target (AggSchedTarget):
(a) In absolute terms
With respect to the Q1 update, there are three snippets to be shared here on WattClarity:
i. On 14th May 2023 we shared how ‘we’re not building enough replacement dispatchable capacity’
ii. On Wed 31st May 2023, we shared ‘Digging further into ‘Aggregate Scheduled Target’, to understand what Dispatchable Capacity is actually required’
iii. A little later on, we’ll delve further into ‘Details to come’.
(b) Ramping from one Dispatch Interval to the next
3) ‘Forecast Convergence‘ for AggSchedTarget
The 47 x coal units still operational in the NEM in Q1 2023 (albeit with 3 remaining units at Liddell now closed in Q2 2023) are a special subset of dispatchable plant that have been addressed in more detail in this particular Appendix – because:
1) They still provide a large share of the Energy consumed in the NEM (and also the ‘Keeping the Lights on Services’);
2) But suffer from the big drawback of high emissions intensity.
What this contains includes:
1) Performance specifically through Q4
2) Coal unit ‘dependability’
In the 180-page analytical component of the GRC2018 we included an extensive focus on the changing nature of different aspects of coal unit ‘dependability’. This was extended and updated in GenInsights21.
Now, in each quarter, we’re extending and updating further, with the inclusion of analysis of:
(a) Changing levels of Unavailability
(b) Three different metrics that help to indicate the changing rate of ‘Sudden Failure’:
… number of Starts, number of ‘Sudden Trip’, and Aggregate Raw Off-Target.
(c) New in these Quarterly Updates, we’re now also separating out all hours in the quarter for each of the remaining coal units into three categories (Operational, Planned Outage and Forced Outage), which makes it clearer which units appear to be struggling and which units are not.
3) We also look at ‘Forecast Convergence‘ for Aggregate Coal Unit Availability across the 47 units operational in this quarter.
4) Each quarter we take an updated look at the Closure Schedule.
(a major increase in analytical content)
In this Appendix, we look at:
1) Regional Energy Balances
2) Regional Transfer Duration Curves
3) Specific interconnector operations (including, new to the Q1 update, the impact of various types of constraint)
4) Renewable energy congestion
5) Changing Marginal Loss Factors (MLFs)
… and in future Editions will add in other aspects.
Please contact us if you have more questions on the above, and please complete this order form and return to us to secure your order, remembering to flag which option you prefer:
Option 1 = Document only (as integrated PDF); or
Option 2 = both:
(a) Document (as integrated PDF) +
(b) Executive Briefing (noting that this is subject to availability).
We look forward to receiving your order.