High wages drive LNG projects offshore
Developers are heading to sea in search of savings, writes James Paton.
The rising cost of building liquefied natural gas plants in Australia, where energy workers earn the highest salaries in the world, is forcing developers out to sea in search of billions of dollars in savings.
Exxon Mobil plans to use the world's largest ship to turn gas into liquid at an offshore field, eliminating the need for investment in pipelines and port facilities. Woodside Petroleum is studying sea-based technology since ditching plans this month for an onshore plant for its Browse project off Western Australia.
After starting work on $175 billion in LNG terminals on land, developers are considering more than $80 billion in floating projects to keep Australia competitive with suppliers in North America and East Africa.
"A lot of people have been saying Australian LNG is now over, it's going to be priced out of the market by US LNG exports and competition from Canada and East Africa," said Citigroup analyst Mark Greenwood. "In our view, we are going to see continued investment in Australia, just a different sort."
The engineering challenges are massive. Shell's Prelude vessel, vying to be the first floating LNG facility in the world, will be as long as the Empire State Building and six times the weight of the largest aircraft carrier.
Exxon proposes a vessel spanning 495 metres, or seven metres longer than the Shell plant.
Australian oil and gas workers earn about $160,000 a year on average, 35 per cent more than employees in the US and almost double the global average, according to a survey this year by recruiting company Hays and Oil and Gas Job Search.
Floating LNG may be almost 20 per cent cheaper than building a project on land for Woodside and its partners in the Browse project, including Shell. Using three offshore vessels to produce the gas would cost an estimated $35 billion, compared with a cost of $43 billion for a new development on land, John Hirjee, an analyst for Deutsche Bank, wrote in an April 12 report.
That's a cost of $2.92 billion per million metric tonnes of output for a floating LNG project producing 12 million tonnes a year, compared with a $3.58 billion cost for a conventional plant.
Of the 90 million tonnes a year of new projects that need to be approved globally in the next three years to satisfy LNG demand by the end of the decade, as much as a third may come from proposed floating LNG plants and expansions of onshore developments in Australia, he said.
Australia's vast gas reserves and proximity to the largest import markets in Asia have put the nation in pole position to meet burgeoning demand in Japan, China and South Korea and become the world's biggest exporter within the decade.
The country has six onshore projects with long-term contracts under construction, with the first of those starting next year, in addition to the three already operating.
The resources boom in Australia has inflated costs to the point where onshore developments are becoming too expensive, while the industry also faces increasing global competition.
Woodside's onshore plant would have created as many as 8000 jobs during construction and generated as much as $50 billion in gross domestic product, according to the company's website.
"The advantage is that a lot of the work can be done outside the high-cost environment of Australia," Anthony Patten, a Perth-based partner and energy specialist at the law firm Allens, said. "We've enjoyed an enormous amount of activity over the past several years, but the costs of Australian projects are going to be high compared with emerging producers like Mozambique and the US."
Shell, Europe's largest oil company, is building the Prelude vessel at Samsung Heavy Industries' shipyard in Geoje, an island off the south-east coast of South Korea. At the peak of construction, the venture will employ 5000 people.
When Prelude is complete, the ship will be towed to a site off Australia about 200 kilometres from the nearest point on the coast, it will chill gas into liquid and transfer the fuel to vessels for transport to customers.
The project is due to start production in about 2017.