CALGARY, Alberta/NEW YORK (Reuters) - Canadian oil producers are running out of options to get crude to market as pipeline and rail capacity fills up, driving prices to four-year lows and increasing the risk of firms having to sell cheaply until at least late 2019.
This will drive down the profit margins for the oil sands industry, already struggling to compete with cheaper and abundant supplies from U.S. shale. A number of foreign oil majors have left Canada’s oil sands to invest in more profitable U.S. shale plays, selling over $23 billion in Canadian assets this year alone.
Canada’s oil sands output is still growing - but only as projects under construction are completed and smaller expansions come online. Oil firms are not commissioning large new projects because they cannot build them profitably with oil in the $50s a barrel.
The deeper discount on crude means next year could be just as tough for Canadian producers from a price perspective as 2017, even though international crude prices have strengthened.
“We have a build-up of supply and that’s only going to get worse next year. We are adding more and more pressure into a constrained export system,” said Wood Mackenzie analyst Mark Oberstoetter.
The volume of crude in storage has hit record levels in western Canada and heavy crude is trading near its widest discount to U.S. crude CLc1 since December 2013, driven by increased supply and a leak on TransCanada Corp’s (TRP.TO) Keystone export pipeline last month.
The discount on Canadian heavy crude blew out to as much as $28 a barrel below the West Texas Intermediate benchmark, pushing the outright price of Canadian barrels to less than $30.
Many traders and analysts expect the discount to be wider in 2018 than the negative $12 a barrel year-to-date average as oil supply rises.
Canada’s oil sands output is forecast to climb by 315,000 barrels per day next year and 180,000 bpd in 2019 to 3.2 million bpd, according to RBC Capital Markets, which described the growth as “unprecedented” and said exports will materially exceed pipeline capacity in early 2018.
RBC downgraded its Western Canada Select discount by $3.50 in both 2018 and 2019 to $15.50 and $17.50 a barrel respectively.
WCS for 2018 is being priced at $20.45 per barrel below WTI, according to Shorcan Energy brokers.
Producers in Alberta are clamoring to get their barrels to market via rail, but railroad companies are reluctant to invest in expanding capacity because of concern that demand for their services is short-term.
Rail firms lost money in the past when they invested in expanding capacity only to see demand from the industry fall when prices collapsed in 2014 or when new pipelines started operation.
Export pipelines are already running close to their limit and proposed new projects such as TransCanada’s Keystone XL and Kinder Morgan Canada’s KML.TO Trans Mountain expansion have been beset by regulatory delays and fierce environmental opposition. No new export pipelines are expected to be built before late 2019 at the earliest when Enbridge Inc (ENB.TO) expects to finish its Line 3 replacement project.
“Canadian producers are now at the mercy of rail given that current pipes are near capacity and production continues to grow as legacy oil sands projects ramp up,” said Michael Tran, director of energy strategy at RBC Capital Markets.
“This pricing underscores how fragile the Canadian energy industry is due to lack of pipeline takeaway capacity.”
Some of the largest oil sands producers such as Suncor and Imperial Oil (IMO.TO) own refineries, which help offset low crude prices with higher refining margins. Smaller producers including MEG Energy (MEG.TO) and Pengrowth Energy PGF.TO have taken out financial hedges to limit their exposure to widening WCS differentials.
Cenovus Energy (CVE.TO) owns the 77,000 bpd Bruderheim rail terminal near Edmonton, Alberta, and leases its own rail cars to make sure it has multiple options to ship crude.
“Having our own crude-by-rail loading facility also decreases the risk of having to compete for potentially expensive capacity during periods of pipeline constraint,” said spokesman Reg Curren.
Canadian Pacific Railway (CP.TO) is asking shippers to lock into minimum one-year commitments to haul barrels, two industry sources said.
The sources added rail companies are either reluctant or showed no interest in monthly, spot deliveries.
A CP spokesman did not respond to requests for comment on contracts.
Traders and producers are wary of committing to long-term rail contracts, which are more expensive than pipeline. It costs around $10-$12 a barrel to ship Canadian crude to the U.S. Gulf Coast, two sources said, versus around $8 by pipe.
CP chief executive Keith Creel told an investors conference in November the company went through a “very painful divorce” with crude-by-rail after a previous fall in oil prices and he would not be making 30-year investment decisions based on two or three years of demand.
The country’s other major railroad Canadian National Railway Co (CNR.TO) has told shippers it will not offer more rail capacity for oil until the second quarter of 2018, three sources said.
Canadian National is currently focused on moving grain for export, said spokesman Patrick Waldron.
John Zahary, CEO, of Altex Energy, which owns five rail terminals in Canada, said activity has doubled in the company yards in the past six months.
“Our phone is ringing off the hook,” he said.
Additional reporting by Jarrett Renshaw in New York; Editing by Simon Webb and Andrew Hay