The electricity system is a giant machine in a giant transition. The task at hand is daunting: to refit the machine so it continues to deliver reliable and affordable power, whilst substantially reducing its greenhouse emissions through the first half of this century.
The future of the grid will not be decided by whether or not to extend the life of an old power station in NSW. It will be delivered by the development of a credible, flexible and bipartisan strategy that businesses and governments can invest behind and adapt over the next generation.
This week the Australian Energy Market Operator (AEMO) produced two separate but related reports which effectively said the same thing: after a decade of policy uncertainty we are at increasing risk of not having enough electricity when we need it. This scarcity is driving prices up and reliability down, both of which are hurting businesses and households.
This next summer AEMO identified as the first of a rolling storm of pinch points where the risk of blackouts in Victoria and South Australia has increased. This information is not new. The biggest thing to change this week is the candour and frankness of their warning.
Like sandbagging before a flood, AEMO, the electricity industry, state governments and a number of industrial customers have already been putting in place measures to mitigate this risk. Some of these measures, like emergency diesel generators, are temporary. Others, like large batteries and contracting businesses to be ready to switch off demand during times of peak demand, are likely to be more permanent.
The current response is piecemeal; a scheme here, a Tesla battery there. With careful planning the relevant participants hope to minimise the risk of blackouts this summer.
But these are more band aid solutions in the absence of the multi-billion dollar investment needed to rebuild a reliable low emission system. That investment requires policy certainty and a bipartisan strategy. This remains elusive.
The underlying pressure on the system is coming from the rolling retirement of Australia’s fleet of coal fired generators. Built largely from the 1960s to the 1980s, they are now reaching the end of their working life and preparing to exit the market.
AGL is the owner of the Liddell Power Station in the Hunter Valley. More than two years ago it signalled its intention to close the asset in 2022. That’s 7 years notice.
The problem isn’t old power stations closing. It’s that we don’t have a plan to replace them. To manage system reliability and affordability the market operator may want to buy some time and seek to extend the life of some of these generators. That may be a sensible and cost effective solution.
Each power station is different in its age, its condition, how it was run during its life, its supply of fuel and how much it would cost to extend its life.
It’s not unlike driving a car bought in the 1970s to work every day. You can do it, but the cost of maintaining an ageing vehicle starts to get prohibitively expensive. And that, in turn, will depend on whether it’s an old Kingswood, or an old Alfa Romeo.
Liddell was driven hard by its NSW Government owners when it was first built. It’s had a harder life than many other generators, and has received substantial reinvestment in most parts of its operating plant over its life.
Decisions about whether or not to extend the life of any existing generator will need to be made on a case by case basis, and as part of a national energy strategy.
The cost of extending the life of old coal, and the terms under which it would run, would need to stack up against competing technology solutions to do the same job. The whole system would need to reflect the emissions targets agreed by successive governments.
If it is not commercially prudent for the owner of a power station to reinvest millions of dollars to extend its life, then who would pay for it? How do we make sure this is the most efficient investment? What are the other options and what do they cost?
These are important and expensive questions. They haven’t yet been considered as part of a national energy strategy we don’t yet have. Instead we have arrived with startling speed to an oddly public commercial negotiation.
We are better off closing the deal on bipartisan and durable national climate and energy policy, and ending a decade of investment gridlock and uncertainty.
The roles and responsibilities of electricity distribution networks are being challenged by the changing mix of resources in the grid. The energy transition is not just about reducing emissions by changing technologies in large-scale generation, it is also about a trend towards more localised, or distributed energy resources (DER). The Australian Energy Council’s latest discussion paper looks at what the transition might mean for distribution networks and customers.
The latest discussion paper in the Australian Energy Council’s “55 by 35” series on Australia’s Energy Future focuses on the implications of the target and the transition to net zero for regional economies in the light of the progressive closure of coal power plants. It recognises that there is a policy case for a focus on these regions, given that coal power plants (and in some cases associated mines) are major employers in those regions.
The latest discussion paper in the Australian Energy Council’s “55 by 35” series on Australia’s Energy Future focuses on hydrogen. The AEC has proposed an interim economy-wide emission reduction target of 55 per cent from 2005 levels by 2035 and the papers consider options for decarbonisation. Hydrogen undoubtedly has considerable potential, but it’s still also a long way away from delivering on that potential.
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