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Diprotodon, an extinct Ice Age marsupial of Australia, would trek long distances each year for food.

Capital is given emergency warning as polluted air from the continent combines with toxic air at home

The mayor of London, Sadiq Khan, has triggered the capital’s emergency air quality alert as polluted air from the continent combines with toxic air in London to create dangerous levels of pollution.

The alerts will see warnings displayed at bus stops, road signs and on the underground. Khan has also asked TV and radio stations across the capital to warn their viewers and listeners in news bulletins.

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As usual, conservative media outlets distorted a climate science paper to advance the denialist agenda

Last week, Nature Geoscience published a study suggesting that we have a bigger remaining carbon budget than previously thought to keep global warming below the 1.5°C aggressive Paris climate target. Many scientists quickly commented that the paper’s conclusion was based on some questionable assumptions, and this single study shouldn’t be blindly accepted as gospel truth.

Conservative media outlets did even worse than that. They took one part of the paper’s analysis out of context and grossly distorted its conclusions to advance their anti-climate agenda.

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The ex-chief scientist says the government should be made to enshrine a zero-emissions target in law.

Solar projects tendering for Queensland government's 400MW of large-scale renewables contracts will have to add storage to their projects.

Green industrial revolution continues at Whyalla, with Adani Group's 140MW solar farm approved for construction.

The City of Adelaide is now a hub for South Australia’s electric vehicle charging network with eight fast charging stations opening today within a new dedicated EV parking area.

Hackett steps down from twin roles at Redflow as company focuses on new manufacturing facility and cutting costs.

The Parker Solar Probe is going to be the first spacecraft to journey deep into the sun's atmosphere.

Whither coal? India's new electrification scheme will dedicate 80% of $2.5bn budget to rolling out solar and battery banks to rural and remote homes.

The 10 MW Clayhill solar farm and storage facility, developed by Anesco, was officially opened by UK climate change minister Claire Perry.

The price of new-build renewable energy is expected to fall significantly relative to new-build coal energy in coming years.

In a recent Conversation FactCheck I examined the question: “Is coal still cheaper than renewables as an energy source?” In that article, we assessed how things stand today. Now let’s look to the future.

In Australia, 87% of our electricity generation comes from fossil fuels. That’s one of the highest levels of fossil fuel generation in the world.

So we have important decisions to make about how we’ll generate energy as Australia’s fleet of coal-fired power stations reach the end of their operating lives, and as we move to decarbonise the economy to meet our climate goals following the Paris agreement.

What will the cost of coal-fired and renewable energy be in the coming decades? Let’s look at the numbers.

Improvements in technology will make renewables cheaper

As technology and economies of scale improve over time, the initial capital cost of building an energy generator decreases. This is known as the “learning rate”. Improvements in technology are expected to reduce the price of renewables more so than coal in coming years.

The chart below, produced by consulting firm Jacobs Group and published in the recent Finkel review of the National Electricity Market, shows the projected levelised cost of electricity (LCOE) for a range of technologies in 2020, 2030 and 2050.

The chart shows a significant reduction in the cost of solar and wind, and a relatively static cost for mature technologies such as coal and gas. It also shows that large-scale solar photovoltaic (PV) generation, with a faster learning rate, is projected to be cheaper than wind generation from around 2020.

Notes: Numbers in Figure A.1 refer to the average. For each generation technology shown in the chart, the range shows the lowest cost to the highest cost project available in Jacobs’ model, based on the input assumptions in the relevant year. The average is the average cost across the range of projects; it may not be the midpoint between the highest and lowest cost project. Large-scale Solar Photovoltaic includes fixed plate, single and double axis tracking. Large-scale Solar Photovoltaic with storage includes 3 hours storage at 100 per cent capacity. Solar Thermal with storage includes 12 hours storage at 100 per cent capacity. Cost of capital assumptions are consistent with those used in policy cases, that is, without the risk premium applied. The assumptions for the electricity modelling were finalised in February 2017 and do not take into account recent reductions in technology costs (e.g. recent wind farm announcements). Independent Review into the Future Security of the National Electricity Market

Wind prices are already falling rapidly. For example: the graph above shows the 2020 price for wind at A$92 per megawatt-hour (MWh). But when the assumptions for the electricity modelling were finalised in February 2017, that price was already out of date.

In its 2016 Next Generation Renewables Auction, the Australian Capital Territory government secured a fixed price for wind of A$73 per MWh over 20 years (or A$56 per MWh in constant dollars at 3% inflation).

In May 2017, the Victorian renewable energy auction set a record low fixed price for wind of A$50-60 per MWh over 12 years (or A$43-51 per MWh in constant dollars at 3% inflation). This is below the AGL price for electricity from the Silverton wind farm of $65 per MWh fixed over five years.

These long-term renewable contracts are similar to a LCOE, because they extend over a large fraction of the lifetime of the wind farm.

The tables and graph below show a selection of renewable energy long-term contract prices across Australia in recent years, and illustrate a gradual decline in wind energy auction results (in constant 2016 dollars), consistent with improvements in technology and economies of scale.

But this analysis is still based on LCOE comparisons – or what it would cost to use these technologies for a simple “plug and play” replacement of an old generator.

Now let’s price in the cost of changes needed to the entire electricity network to support the use of renewables, and to price in other factors, such as climate change.

Carbon pricing will increase the cost of coal-fired power

The economic, environmental and social costs of greenhouse gas emissions are not included in simple electricity cost calculations, such as the LCOE analysis above. Neither are the costs of other factors, such as the health effects of air particle pollution, or deaths arising from coal mining.

The risk of the possible introduction of carbon emissions mitigation policies can be indirectly factored into the LCOE of coal-fired power through higher rates for the weighted average cost of capital (in other words, higher interest rates for loans).

The Jacobs report to the Finkel Review estimates that the weighted average cost of capital for coal will be 15%, compared with 7% for renewables.

The cost of greenhouse gas emissions can be incorporated more directly into energy prices by putting a price on carbon. Many economists maintain that carbon pricing is the most cost-effective way to reduce global carbon emissions.

One megawatt-hour of coal-fired electricity creates approximately one tonne of carbon dioxide. So even a conservative carbon price of around A$20 per tonne would increase the levelised cost of coal generation by around A$20 per MWh, putting it at almost A$100 per MWh in 2020.

According to the Jacobs analysis, this would make both wind and large-scale photovoltaics – at A$92 and A$91 per MWh, respectively – cheaper than any fossil fuel source from the year 2020.

It’s worth noting here the ultimate inevitability of a price signal on carbon, even if Australia continues to resist the idea of implementing a simple carbon price. Other policies currently under consideration, including some form of a clean energy target, would put similar upward price pressure on coal relative to renewables, while the global move towards carbon pricing will eventually see Australia follow suit or risk imposts on its carbon-exposed exports.

Australia’s grid needs an upgrade

Renewable energy (excluding hydro power) accounted for around 6% of Australia’s energy supply in the 2015-16 financial year. Once renewable energy exceeds say, 50%, of Australia’s total energy supply, the LCOE for renewables should be used with caution.

This is because most renewable energy – like that generated by wind and solar – is intermittent, and needs to be “balanced” (or backed up) in order to be reliable. This requires investment in energy storage. We also need more transmission lines within the electricity grid to ensure ready access to renewable energy and storage in different regions, which increases transmission costs.

And, there are additional engineering requirements, like building “inertia” into the electricity system to maintain voltage and frequency stability. Each additional requirement increases the cost of electricity beyond the levelised cost. But by how much?

Australian National University researchers calculated that the addition of pumped-hydro storage and extra network construction would add a levelised cost of balancing of A$25-30 per MWh to the levelised cost of renewable electricity.

The researchers predicted that eventually a future 100% renewable energy system would have a levelised cost of generation in current dollars of around A$50 per MWh, to which adding the levelised cost of balancing would yield a network-adjusted LCOE of around A$75-80 per MWh.

The Australian National University result is similar to the Jacobs 2050 LCOE prediction for large-scale solar photovoltaic plus pumped hydro of around A$69 per MWh, which doesn’t include extra network costs.

The AEMO 100% Renewables Study indicated that this would add another A$6-10 per MWh, yielding a comparable total in the range A$75-79 per MWh.

This would make a 100% renewables system competitive with new-build supercritical (ultrasupercritical) coal, which, according to the Jacobs calculations in the chart above, would come in at around A$75(80) per MWh between 2020 and 2050.

This projection for supercritical coal is consistent with other studies by the CO2CRC in 2015 (A$80 per MWh) and used by CSIRO in 2017 (A$65-80 per MWh).

So, what’s the bottom line?

By the time renewables dominate electricity supply in Australia, it’s highly likely that a price on carbon will have been introduced. A conservative carbon price of at least A$20 per tonne would put coal in the A$100-plus bracket for a megawatt-hour of electricity. A completely renewable electricity system, at A$75-80 per MWh, would then be more affordable than coal economically, and more desirable environmentally.

Ken Baldwin receives funding from the Australian Research Council.

AGL outlines plans to install 250MW of battery storage at Liddell, and to invest in Bayswater upgrade, new gas generators, demand response, and huge amount of wind and solar to replace Liddell.

Goulburn Council to commission feasibility studies into installing floating solar on government water stores, to slash power costs.

Green Bond issues expected to surpass $US100 billion for the first time in a single year in 2017.

‘Clean growth’ report steps into scrapping of green deal void and reinstates all new homes be zero carbon by 2020

Progress in making Britain’s homes more energy efficient has stalled, but the government could salvage billions in wastage by taking a few key steps, a new report with wide backing has found.

Ministers are preparing a new “clean growth” plan after the scrapping of the green deal, which left the UK without a government policy on making homes more energy efficient and tackling fuel poverty.

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Northvolt is going to build Europe’s largest and most advanced lithium-ion battery factory in Sweden. Supported by ABB’s industrial automation expertise, the factory will supply European customers in the automotive and key industries with high quality and customizable battery solutions.

With the Japanese whaling season about to begin in the Southern Ocean, Greens Senator Peter Whish-Wilson is lobbying Japanese MPs to end the slaughter.

Rising gas costs are “the single biggest factor in the current rise in electricity prices”.

What is most noteworthy about this statement is not the fact that it is true, but that it was made by Prime Minister Malcolm Turnbull, many of whose party colleagues remain convinced that renewable energy is the real bogeyman.

Read more: Big gas shortage looming, but government stays hand on export controls

Turnbull’s comments were made in response to a report released this week by the Australian Energy Market Operator (AEMO), which yet again warns of impending gas shortages.

I argue below that renewables are a solution to the problem, rather than its cause. But first, is there actually a gas crisis?

A gas crisis?

Although AEMO has predicted a potential gas shortfall for the east coast, there is no shortage of gas. Unprecedented amounts are being produced and exported as liquified natural gas (LNG) from terminals in Queensland, while at the same time the domestic market is being starved, driving prices sky-high.

Read more: Memo to COAG: Australia is already awash with gas

Without government action there could indeed be a domestic shortfall next year, but the government has already set in place a system of export restrictions to ensure domestic supply. These restrictions have not yet been invoked, but the crisis for the government is that they may have to be, and the decision must be made before November 30.

Emergency export restrictions are an intervention of last resort for a governing party built on free-market principles. They are necessary because the government has failed to champion a longer-term and less interventionist strategy, such as the reservation of a certain percentage of gas produced from new gas fields for domestic use. Western Australia has had a policy of 15% reservation for many years and other states are following suit.

Read more: Our power grid is crying out for capacity, but should we open the gas valves?

Not only is there plenty of gas being produced, but it would be relatively painless to divert some of it to the domestic market. AEMO notes several times in its report that producers have some flexibility in where they send their gas. In particular, a significant proportion of the exported gas is not under long-term contract but is destined for the overseas spot market, where surplus energy is traded for immediate delivery. This gas could easily be diverted to the east coast market.

On current projections, 63.4 petajoules of gas is destined for the spot market in 2018. To put this in context, the projected shortfall is 54PJ in 2018 and 48PJ in 2019. In other words, the uncontracted gas destined for the spot market is more than enough to make up the expected shortfall.

Turnbull is also arguing that the potential shortage is due to state bans on gas exploration and production. However, the production costs associated with as-yet-untapped reserves and resources in those states are much higher than for Queensland. Thus, even in the absence of bans it would still make sense to target untapped Queensland resources first.

Moving the gas south

The extra gas released in Queensland for domestic use would need to be transported to the southern states by pipelines that are already close to capacity. This is a potential problem. However, it could be resolved by means of “gas swaps”.

Gas produced in the southern states that has been contracted for sale through the Queensland terminals could be swapped for gas released by Queensland producers for distribution to the southern states. This would avoid bottlenecks and gas transportation costs.

In the longer term, the problem could be solved by AGL’s proposal to establish a liquid natural gas (LNG) import terminal (a regasification plant) at Western Port in Victoria.

This facility could process LNG either from Queensland or from further afield. The terminal would have the potential to provide all of Victoria’s household and business customer gas needs. If all goes to plan, AGL will begin construction in 2019 and bring the terminal into operation by 2020–21.

Our free-market government is now firmly in interventionist mode, with gas export restrictions and plans to fund a Snowy pumped hydro scheme. There is even a proposal to subsidise the continued operation of the AGL’s Liddell coal-fired power station beyond its scheduled closure in 2022.

Read more: Baffled by baseload? Dumbfounded by dispatchables? Here’s a glossary of the energy debate

But rather than continuing to badger AGL about keeping Liddell open, the government would be wiser to press the firm to bring its regasification plant online as soon as possible. Not only does it make economic sense, but it is greatly preferable from an environmental point of view.

The renewables solution

Another way to deal with the predicted gas shortfall is to reduce demand. According to AEMO figures, gas-powered electricity generation in 2018 is expected to require 176PJ of gas, dropping to 135PJ in 2019. The lower demand in 2019 is due to increased renewable energy generation, as well as increased consumer energy efficiency.

Recalling that the shortfall in gas for 2018 is 48PJ, it is apparent that this shortfall would be wiped out by a 30% reduction in gas used for gas-fired power generation. Based on 2016 figures, that would require an increase of roughly 30% in power generation from renewables.

Given the relatively short time it now takes to build new renewable generators, this is a very promising path. Coupled with battery storage or pumped hydro, these new generators would provide dispatchable power exactly as gas does. All that is required is for the government to implement the right policy settings.

Finally, state government policies may already be taking us in this direction. The Queensland government recently announced a major program of incentives for solar power. This will significantly increase renewable power generation and dampen the demand for gas-fired power. AEMO notes this development but states explicitly that this has not been taken into account in its projections.

For whatever reason, AEMO’s final conclusion is not as gloomy as its analysis might suggest. It states that the gas situation in eastern and south eastern Australia “is expected to remain tight”. Rather than calling for action, it considers that the situation “warrants continued close attention and monitoring”. Amid all the talk of impending crisis, what we need is steady pressure on the steering wheel, rather than a sharp swerve.

Andrew Hopkins does not work for, consult, own shares in or receive funding from any company or organisation that would benefit from this article, and has disclosed no relevant affiliations beyond the academic appointment above.