By Edward Welsch 
 

ALBERTA, Canada--Ten years ago, new oil field technologies unlocked vast crude supplies from western Canada's oil-sands deposits, propelling America's northern neighbor to the top echelon of the world's petroleum repositories.

Now oil companies here are experimenting with technologies that could unlock even more reserves from what is some of the world's heaviest and stickiest petroleum. The new technologies could also drive down the cost of producing oil in Canada.

One consortium aims to get oil flowing to the surface by sending radio waves from huge antennae pushed through wells deep underground-- adopting technology first developed for the U.S. government to eavesdrop on underground bunkers.

Another company is working on inserting electrical heating coils into wells to melt the oil, while other firms are tinkering with petroleum-based solvents they hope to pump into wells to get more oil out.

All the experimentation is aimed at improving a standard method of oil-sands extraction: so-called steam-assisted gravity drainage, or SAGD. (That is pronounced "Sag-Dee" in industry parlance.) That technology is itself a recent breakthrough-- essentially injecting superheated steam into wells to heat deposits of sticky bitumen, a form of petroleum, making it liquid enough to be pumped to the surface.

The technology was commercialized in Canada's northern Alberta province early last decade, and helped enable oil companies to tap deeper oil-sands reserves. For decades, most oil-sands development had more in common with strip mining than conventional oil drilling. Companies dig up a mix of bitumen and quartz sand and wash the sludge down with hot water to extract the bitumen.

SAGD quintupled the amount of bitumen that may be possible to recover in Canada, and helped lift Canada's overall recoverable oil reserves to No. 3 in the world, behind Saudi Arabia and Venezuela.

But those reserves are only a 10th of the 1.7 trillion barrels of bitumen found in Canada. Alberta's Energy Resources Conservation Board estimates there are also more than 400 billion barrels of bitumen trapped in carbonate rock formations in Alberta, mostly in a large formation called the Grosmont that stretches across the center of the province.

"If we postulated that 25% of that can be recovered, Canada could move to No. 1" in world oil reserves, said Glen Schmidt, chief executive of privately owned Calgary energy-technology company Laricina Energy Ltd.

Laricina is one of several companies including Royal Dutch Shell PLC, Athabasca Oil Corp. and Husky Energy Inc. that are adapting SAGD technology to rock formations like the Grosmont and trying out new enhancements to cut the use of fresh water and energy, which will bring down the overall cost and greenhouse gas emissions of operations there. While SAGD doesn't gobble up as much surface area as conventional oil-sands mining, it still uses lots of energy and water. That makes it expensive and carries a big greenhouse-gas footprint.

Basic SAGD technology uses two horizontal wells drilled parallel to each other, one above the other. Natural gas is used to boil water into steam, which is injected underground into the top well. The steam heats and softens the bitumen, separating it from the sand, causing it to drip down to the bottom well, which sucks it back up.

Laricina is part of a consortium including large Canadian energy companies Suncor Energy Inc. and Nexen Inc. that is testing replacing the steam with an antenna, developed by Melbourne, Fla., telecommunications-equipment manufacturer Harris Corp. After being fed down a well, the antenna blasts out heat, warming the bitumen.

Nexen announced Monday that Chinese international energy company Cnooc Ltd. plans to acquire it for $15.1 billion.

Mr. Schmidt said early tests show the technology could cut energy use by 40%. It also removes the high upfront costs of water treatment and steam generation facilities. That could cut the cost the cost of SAGD production, which is currently around $55 to $65 a barrel for most projects.

"If we eliminate steam, we eliminate potentially 60% of the cost of a facility, which is huge," he said. The technology could be ready as soon as 2019.

The antenna project got started back in 2008, when Harris was working on technology aimed at improving underground listening capabilities for the U.S. government.

As part of its research, Harris executives sought out oil field experts experienced in horizontal drilling techniques.

"We were trying to gain access to underground facilities, underground locations, so we had to bring in people who had specialties in horizontal drilling," Wes Covell, a Harris vice president, said. He declined to be more specific about what he said was a classified project.

Harris executives had an epiphany when the drilling experts mentioned the Canadian oil industry's problem of getting energy-efficient heat to travel down horizontal wells into the bitumen reservoirs deep underground.

Harris and other antenna designers try to reduce electromagnetic heat as much as possible to improve the efficiency of a radio antenna for communication. Harris "realized that we can take our antennae and instead of using them for communications, we can use them as a source of electromagnetic energy that generates heat," Mr. Covell said.

Athabasca Oil, another big Canadian oil producer, is testing a similar electric-heating technology to unlock bitumen from carbonate rock. The company inserts electric coils, made of the same material as heating elements on a stovetop, into wells. If tests are successful, Athabasca plans to start a commercial project for its technology by 2018.

Laricina and several other companies are also testing adding light hydrocarbon solvents to steam in SAGD wells to boost output. The solvent dilutes bitumen, making it easier to flow.

Cenovus Energy Inc. is working on a solvent project that could be rolled out commercially in 2017.

Jason Abbate, head of production engineering at one of Cenovus's projects, said solvent technology could increase oil production rates by up to 25% and cut the amount of steam and natural gas use by up to 30%. It could also improve the percentage of oil that producers can capture from bitumen deposits.

"If you can get 80% to 90% of that rather than the regular 70% with SAGD, there's a big economic benefit for us," Mr. Abbate said.

Write to Edward Welsch at edward.welsch@dowjones.com

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