Oklahoma City-based Devon Energy Corp. eschewed all talk on Wednesday that its North American onshore properties are anything but stellar by announcing a $1 billion increase to the 2012 capital spending budget, with nearly all of the money to be focused on exploration efforts in the company’s in-house unconventional portfolio.
Mergers and acquisitions? Devon has about $7 billion in cash from selling its deepwater Gulf of Mexico and international assets over the past two years. However, other than bolt-on land deals that enhance the U.S. and Canadian portfolio, they are off the table, CEO John Richels told financial analysts during a morning-long presentation in Houston.
“People think we need to do an acquisition to grow. We don’t. We have no interest in acquiring assets,” Richels said. The management team hasn’t considered making an acquisition “for five minutes.”
The exploration and development plan that the team outlined through 2016 “is based on existing assets,” he said, which at the end of 2011 included on the natural gas side 9.5 Tcf of reserves, according to the latest report by the American Gas Association (AGA) (see related story).
The reserve total puts them in rarefied company near the top of the chart after ExxonMobil Corp., Chesapeake Energy Corp., BP plc and ConocoPhillips. Devon was fifth in production with 740 Bcf after ExxonMobil with 1.6 Tcf, Chesapeake Energy with 1 Tcf, Encana Corp. with 857 Bcf and Anadarko Petroleum Corp. with 852 Bcf, according to AGA’s report.
If slow and steady wins the race, Devon surely will be wearing the gold medal. The darling of the big unconventional gas players in the last decade, Devon was the smart one, the company that listened to George Mitchell’s insight into combining horizontal drilling with hydraulic fracturing — and then bought his company for only $3.1 billion in cash and stock — and then expanded the original Big Daddy Shale, the Barnett, into something that everybody since has attempted to duplicate or better.
With its focus now trained on North America’s onshore, the management team is confident enough to boost this year’s capital spending to $6.3 billion from an original target of $5.3 billion — at a time when other onshore operators are slashing spending.
Nearly all of the new growth will be for liquids and oil. No dry gas drilling will be done until prices cooperate, said Richels.
Compound annual production growth, based on Devon’s current portfolio, is set to grow at a rate of 16-18% between now and 2016. Production is forecast to be up to 340 million boe from the current figure of 255 million boe.
Devon remains a gas-weighted company, but it has a boat-load of properties across the United States and Canada that include a lot of liquids and oil. The 3 billion boe in total proved reserves gives the company “flexibility” in deciding where to drill, exploration chief Dave Hager said.
For instance, in the final quarter of 2011 Devon’s production was weighted 45% to oil, 36% to natural gas liquids (NGL) and 19% to natural gas. The company now has 16.2 billion boe of risked resource, and 31.8 billion boe of unrisked resource. Of the 16.2 billion boe of risked resources, Devon has more gas (52%), 8.4 billion boe; followed by oil (29%), 4.7 billion boe; and NGLs (19%, 3.1).
“In the last couple of years we have fundamentally changed the focus of the company and we are strictly an onshore North American player,” said Richels. “Today there are tremendous opportunities at Devon.”
By 2016, he said, Devon expects to still be about 48% gas-weighted, but it should be 32% weighted to oil and 20% weighted to NGLs. Within five years the company estimates that it will be producing 905-055 million boe/d, “with more than 50% liquids.”
The company plans to “organically generate projects,” and become a “first or early mover,” which has often given it low entry costs in acreage and royalty fees. “Scale breeds efficiency,” said the CEO.
“We’ve done a very good job over the years of high-grading the portfolio, taking assets that might have at one point been good and moving them out. We’ve sold about $17 billion of properties over the last 10 years, and we continually try to high-grade the asset base. We try to generally develop a strong midstream presence in key plays…to improve our effectiveness as a company and to give us valuable insights into the markets…”
The company is a lot less flashy than some of its peers in bragging about what it has or doesn’t have, but that doesn’t mean the management team hasn’t been working hard. No, Devon doesn’t have a position in the Marcellus Shale. But don’t let that lack of superstar acreage fool anybody.
Devon remains the leading acreage holder and producer in the Barnett Shale, which, as it turns out, is something of a liquids monster. Long one of the biggest players in the legendary Permian Basin, where producers now are clambering to gain a toehold, Devon recently secured a 500,000 net acre position in the basin’s emerging Cline Shale — making it the biggest leaseholder there.
It’s also got solid holdings in some of the best unconventionals, which include the Utica Shale in Ohio and Michigan, as well as A1 Carbonate in Michigan. Also awaiting development — all mostly held by production — are holdings in the Tuscaloosa Marine Shale, Mississippian Lime, Cana Woodford, Granite Wash, Powder River Basin, Washakie, Horn River Basin, Jackfish and Pike.
“We’re very confident that there are a lot of oil and liquids-rich opportunities to be found in North America,” said Hager.
Another joint venture (JV) in the onshore, which would be about half the size of the $2.5 billion deal that Devon completed early this year with China Petroleum & Chemical Corp. — or Sinopec — also is likely in 2013, said Hager (see Shale Daily, Jan. 4). He didn’t offer any details, but said at one point that the Cline Shale might be a candidate for a JV.
Hager also disclosed that Devon has secured around 250,000 net acres in a new oil play in the North American onshore. The company wants to secure 500,000 net acres before divulging any more information, he said.
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