WASHINGTON (Reuters) - The prospects for bringing large amounts of Canadian heavy crude oil into the United States by train is a contentious issue as the U.S. government weighs whether to allow the controversial Keystone XL pipeline to go ahead.
An assumption that oil would move by rail without Keystone was a key part of a U.S. State Department report in March that found development of Canada’s oil sands region will proceed at roughly the same rate, with or without the pipeline.
That finding undercut warnings from environmentalists that the pipeline would lead to a spike in greenhouse gas emissions.
Proponents for the roughly 1,200 mile pipeline, delivering the oil in Canada’s Alberta province to refineries on the U.S. Gulf Coast, say moving huge volumes of crude by rail would be dirtier and more prone to mishap than a pipeline and the market would adopt rail if the project were halted. The State Department report endorses that view.
But some industry officials, energy analysts and recent data raise questions about whether the industry is really eager to adopt crude-by-rail should the U.S. government rule against the TransCanada Corp TRP.TO pipeline.
They say train transport is so expensive that Canadian heavy crude, produced by processing bituminous sand, isn’t likely to reach Texas and Louisiana in Keystone-like quantities by rail.
These experts also point to plentiful supplies of lighter crude oil from the Bakken shale formation in North Dakota, which is roughly 900 miles closer to the Gulf than the hub of Canadian oil sands production, and plenty of heavy crude from traditional sources such as Saudi Arabia, Mexico and Venezuela, as signs that Gulf Coast refiners can get along without Keystone.
The U.S. government is expected to make a final decision before the end of the year on the Keystone XL pipeline, which is designed to carry as much as 830,000 barrels per day, most of it from Canada.
Comments on the State Department’s environmental assessment are due by April 22, and will be made publicly available, an official said on Wednesday.
The State Department report cites two industry studies to predict that 200,000 barrels a day or more of Canadian heavy crude oil will reach Gulf Coast refiners by train by the end of this year.
Officials used that figure to bolster their argument that the oil industry has already decided rail is a good option for moving oil sands crude. “Limitations on pipeline transport would force more crude oil to be transported via other modes of transportation, such as rail, which would probably (but not certainly) be more expensive,” the State Department said.
But one of the sources for the 200,000 barrels per day estimate, Calgary investment bank Peters & Co, says its forecast was misunderstood as being for just Gulf Coast-bound oil when it included shipments to Eastern Canada and other refiners.
“We haven’t tracked exactly where those barrels are going,” said Tyler Reardon, a spokesman for Peters & Co.
The other source for the number, Hart Energy, did predict in a report last year that 250,000 barrels per day of heavy crude from Western Canada would be reaching the Gulf Coast before the end of this year but its analysts are reviewing that forecast.
“Hart Energy continues to carefully monitor flows from Western Canada,” said Susan Emfinger, a spokeswoman for the Houston energy consultant.
The latest figures from the U.S. Energy Information Administration show heavy crude shipments to the Gulf Coast from Canada by rail have a long way to go to meet the 200,000 figure. They have not exceeded 30,000 barrels per day in any of the past 12 months, though they did rise by two thirds to 25,000 barrels per day in January, the last month for which there are figures, from 15,000 in January 2012.
In fact, EIA data shows that little heavy crude from Canada is reaching the Gulf Coast via any route, with about 75 percent of 33 million barrels of heavy Canadian crude being processed in the Midwest in January and only 7 percent of it being processed further south. Other destinations account for the remainder.
“We just are not seeing those kinds of big deliveries to the Gulf Coast,” said Michael Wojciechowski, head of downstream Americas research at Wood Mackenzie, an energy research and consulting firm.
A State Department official said crude-by-rail is fast-evolving and is one viable alternative to pipelines.
“The industry sees rail as a one possible solution to moving crude oil, particularly in the absence of a pipeline,” said the official who was not authorized to speak publicly about the project.
“We will continue to evaluate its potential and expect substantial public input on the issue.”
Graphic on rail shipments of Canadian heavy crude: link.reuters.com/xyn47t
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Trains can be effective in moving oil. The railroad company Burlington Northern Santa Fe, owned by Warren Buffett's Berkshire Hathaway BRKa.N, has 228 so-called unit trains on the tracks carrying hundreds of thousands of barrels of Bakken crude at any given time.
The use of unit trains - about 100 tank cars linked together on a dedicated route - is what pushed BNSF’s North Dakota crude-by-rail volumes to about 500,000 barrels per day at the end of 2012 from about 70,000 barrels per day 18 months earlier.
There are not currently any unit trains running from Western Canada to the Gulf Coast, industry sources said.
“Rail is not a replacement for pipelines. It is going to be a niche business,” said Gary Kubera, the president of Canadian chemicals manufacturer Canexus, which runs a rail terminal just north of Edmonton that it is expanding so it can transport more heavy oil to the U.S. East Coast, principally for the production of asphalt.
And the expense of getting the Canadian crude to the Gulf would be greater given the additional 900 miles distance and the heavier nature of the oil.
A standard tank car can carry about 700 barrels of light oil, but the fuel wrung from oil sands is so dense that it must either be diluted by about 20 percent or move in a specialty car that can hold only about 550 barrels, according to Jarrett Zielinski, an executive with Torq Transloading, a Canadian company that advises oil sand producers on such shipments.
The logistical challenges to moving heavy crude by rail can be overcome, industry officials and analysts say, but the economics are not so clear-cut.
While the State Department says in the report that moving a barrel of heavy crude through a Keystone pipeline would cost no more than $10 a barrel, oil sand producers say they are facing costs closer to $30 a barrel by train.
Those economics are tenuous, said Sandy Fielden, director of energy analytics with RBN Energy LLC in Houston, who has studied crude-by-rail. “If rail were such a terrific option now out of Western Canada, why haven’t more producers switched from pipeline to rail?”
Gulf Coast refiners are specialists at turning heavy, sulfurous crude from Mexico and Venezuela that arrives by tanker into clean-burning gasoline for cars, so they are already equipped to process Canadian oil sands.
The problem, analysts say, is that the Canadian crude will have to be priced to compete against those shipments, as well as crude arriving at the Gulf refineries from Saudi Arabia.
Mayan crude, the Mexico benchmark akin to oil sands crude, was trading at about $106 a barrel in March, while the Canadian product was valued at about $83 in markets north of the border. Oil sand producers therefore had incentives to move a barrel of their product to the Gulf Coast if they could do so under the roughly $23 spread, said Fielden.
Midwest refiners and existing pipelines are able to absorb oil sands production for now, the Canadian Association of Petroleum Producers has said, but producers will face a critical shortage of pipelines by the end of next year.
“The cheapest way to get from point A to point B is a pipeline,” said Raymond James analyst Steve Hansen. “That is why Keystone has got to go ahead.”
Reporting by Patrick Rucker; Additional reporting by Jeffrey Jones in Calgary; Editing by Tim Dobbyn
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