- Liquefied natural gas (LNG) and thermal coal prices in Asia have been roaring ahead in recent months amid strong demand.
- But while welcome news for the commodity producers, the rally is a longer-term boon to their main rival, renewable energy.
- Spot LNG prices have nearly doubled since the post-winter low of $5.60 per million British thermal units (mmBtu), ending last week at $10.95.
A recent news article published in the Reuters by Clyde Russell states that Coal and LNG’s surge in Asia plays into renewable energy hands.
Demand driven by China
The demand has been largely driven by China, which imported 7.31 million tonnes in May, up from 6.52 million in April and the strongest month since January.
China has imported 33.22 million tonnes in the first five months of 2021, up by close to a third from the 25.62 million imported in the same period in 2020.
While China is driver of spot LNG prices, it’s also playing a role in boosting thermal coal prices, even though its imports are actually weaker so far this year.
China’s total coal imports
China’s total coal imports were 21.04 million tonnes in May, down from 21.73 million in April, according to official customs data. And for the first five months of the year, China’s coal imports were 111.17 million tonnes, down a quarter from the same period in 2020.
China’s unofficial ban
China’s unofficial ban on imports from Australia, the world’s second-biggest shipper of thermal coal behind Indonesia, has roiled markets, forcing Chinese traders and utilities to scramble for coal from alternatives such as Indonesia and Russia.
This has driven up the prices of coal from these producers, in turn forcing India, the world’s second-biggest importer, to increasingly switch away from Indonesia, its former number one supplier, and buy Australian coal instead.
That, coupled with strong demand from Japan and South Korea for high-grade Australian coal, leaves the stars aligned for strong price gains across Asia’s seaborne coal grades.
The benchmark weekly index
The benchmark weekly index for Australian high-grade thermal coal at Newcastle Port, as assessed by commodity price reporting agency Argus, rose to a decade high of $121.48 a tonne in the week to June 4.
That level is almost triple the 2020 low of $46.37, plumbed last September at a time when many Asian economies were locked down as part of efforts to combat the coronavirus pandemic.
Lower-grade Indonesian coal has also performed well, ending last week at $55.04 a tonne, up 143% from its low point in September 2020.
Already, coal-fired and natural gas-fired power plants struggle to compete with renewables such as solar and wind, even when battery back-up storage is factored in.
A recent report compiled by Australia’s science agency CSIRO and the Australian Energy Market Operator showed that the current capital cost of building a new coal-fired power plant using higher-grade fuel was about A$4,450 ($3,435) per kilowatt.
Combined cycle gas-fired plant
A combined cycle gas-fired plant came in A$1,801 per kilowatt, while large-scale solar was A$1,408 and onshore wind was A$1,951.
An integrated solar plant with two hours of battery storage had a capital cost of A$2,139, above the cost of a combined cycle gas plant – but less than half of a new coal-fired plant.
It also excludes the impact of any potential climate change policies being implemented, such as carbon taxes or emissions trading.
An indication of what a carbon-constrained future might mean for coal was that a coal-fired plant with carbon capture and storage was assessed at a capital cost of A$9,311 per kilowatt, rendering it completely uncompetitive with any other type of electricity generation in the study.
Several Asian countries, such as Bangladesh and Pakistan, have recently signalled an end to building coal-fired power plants, and the likelihood of new plants that are reliant on imports being built is rapidly retreating across the region.
LNG, more climate-friendly
LNG producers view their fuel as a more climate-friendly alternative to coal. But while capital costs are competitive with renewables currently, any utility opting for a gas-fired plants based on LNG imports faces risks not apparent with opting for renewables instead.
Chief among them is what has happened in recent months to prices, with wild swings in the spot market: uneven demand caused by a colder-than-expected northern winter drove prices to a record high, following soon after the pandemic caused a slump to a record low in the middle of last year.
Price volatility and security of supply may be LNG’s Achilles heel in Asia, as is the risk that the fuel is increasingly targeted by climate activists, who have already made coal-fired power developments increasingly difficult.
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