OREANDA-NEWS. November 12, 2012. Devon Energy Corporation (NYSE:DVN) reported a net loss of USD 719 million for the quarter ended September 30, 2012, or USD 1.80 per common share (USD 1.80 per diluted share). A USD 1.1 billion non-cash asset impairment charge was the primary driver of the quarterly loss, reported the press-centre of Devon Energy.

Adjusting for this and other items securities analysts typically exclude from their published estimates, the company earned USD 355 million or USD 0.88 per diluted share in the third quarter of 2012.

The company generated cash flow from operations of USD 1.4 billion during the third quarter. Combined with USD 533 million in cash payments from the closing of its joint venture agreement with Sumitomo and other minor asset sales, Devon’s cash inflows totaled USD 1.9 billion in the quarter.

Strong Oil Growth Drives Production Increase
Devon continued to deliver strong oil production growth in the third quarter of 2012. Oil production averaged 143,000 barrels per day, a 14 percent increase compared to the third quarter of 2011. This was achieved in spite of the scheduled shut-down for facilities maintenance at our Jackfish 1 oil sands project, which reduced production by approximately 10,000 barrels per day. Regionally, the most significant growth came from the company’s U.S. operations, where year-over-year oil production increased 26 percent.

In total, Devon’s production averaged 678,000 oil-equivalent barrels (Boe) per day in the third quarter, a 3 percent increase compared to the year-ago quarter. Year-over-year declines in natural gas volumes driven by reduced activity levels in liquids-rich gas projects partially offset the company’s oil production growth in the third quarter.

“Devon’s capital program has delivered strong results this year with aggressive drilling programs in oil-focused basins,” said John Richels, president and chief executive officer. “As we have pursued higher-returning oil projects, we also have de-emphasized natural gas drilling, limiting overall production growth. This is exactly the right tactical decision for Devon in this environment and is consistent with our longstanding strategy to optimize returns as opposed to top-line production growth.”

Permian Basin Results Lead Operating Highlights
Permian Basin oil production increased 35 percent over the third quarter of 2011. Oil production accounted for nearly 60 percent of the company’s 65,000 Boe per day produced in the Permian during the third quarter.

In the Bone Spring and Delaware plays in the Permian Basin, the company added 25 new wells to production in the third quarter 2012. Initial 30-day production from these wells averaged 575 Boe per day.

Also in the Permian, Devon brought five Midland-Wolfcamp Shale wells online in the third quarter with initial 30-day production averaging 560 Boe per day.

In September, Devon closed its USD 1.4 billion joint venture agreement with Sumitomo covering 650,000 net acres in the Permian Basin. Devon has now successfully entered into two exploration joint ventures during 2012, delivering almost USD 4 billion in value to the company.

In Canada, net production from Devon’s Jackfish 1 and Jackfish 2 oil sands projects averaged 44,000 barrels per day in the third quarter. This represents a 24 percent increase in oil production over the year-ago quarter.

Construction of Devon’s third Jackfish oil sands project is now approximately 45 percent complete, with plant startup expected by year-end 2014.

The company’s third quarter activity in the Mississippian Lime play in Oklahoma was highlighted by the increase in activity to 13 operated rigs. Results from the Mississippian play continue to support Devon’s target economics.

Devon brought seven operated Granite Wash wells online in the third quarter. The average 30-day production rate from these wells was 1,065 Boe per day.

The company’s Cana-Woodford Shale production averaged 283 million cubic feet of natural gas equivalent per day in the third quarter 2012. Third-quarter liquids production increased 64 percent compared to the prior-year quarter to 13,000 barrels per day.

Net production in the Barnett Shale totaled 1.4 billion cubic feet of natural gas equivalent per day in the third quarter. Liquids production increased 11 percent compared to the third quarter of 2011 to 51,000 barrels per day, accounting for 22 percent of total Barnett production.

Oil and Gas Sales Total USD 1.7 Billion; Natural Gas Hedge Position Strengthened
Revenue from oil, natural gas and natural gas liquids sales totaled USD 1.7 billion in the third quarter of 2012, an 18 percent decline from the third quarter of 2011. Lower realized prices for all three products more than offset increased production. Cash settlements related to the company’s oil and natural gas hedges boosted revenue by USD 243 million or USD 3.89 per Boe in the third quarter of 2012.

The recent rise in natural gas prices has provided Devon the opportunity to add attractive hedges for next year. For the full-year 2013, the company now has approximately 1.0 billion cubic feet per day of natural gas production protected at a weighted average floor price of \\$3.88 per thousand cubic feet. Devon’s 2013 hedge position covers volumes equal to about 40 percent of the company’s current rate of natural gas production.

In the third quarter of 2012, the company’s marketing and midstream operating profit reached \\$109 million. The solid results were aided by the resumption of operations at the company’s Gulf Coast Fractionators facility in Mont Belvieu following the completion of a recent plant expansion.

Operating Costs Below Expectations
The company’s pre-tax, cash costs of USD 877 million, or USD 14.04 per Boe, were lower than forecasted for the third quarter. Pre-tax, cash costs per unit of production were 4 percent higher than the third quarter of 2011 but declined 2 percent from the second quarter of 2012. Cost containment efforts and increased production offset higher activity levels in oil-focused basins. In general, oil projects are more expensive to produce and have higher operating costs than gas production.

Balance Sheet and Liquidity Remain Strong
With third quarter net cash inflows roughly equal to capital expenditures, the company ended the quarter with a very strong balance sheet. At September 30, 2012, the company’s cash and short-term investments totaled USD 7.5 billion, and Devon’s net debt to adjusted capitalization was just 15 percent.

Impairment Charge Methodology
On a quarterly basis, the carrying value of Devon’s oil and natural gas assets are subject to a “ceiling test.” Under the full-cost method of accounting, the net book value of the company’s oil and gas properties, less related deferred income taxes, may not exceed a calculated ceiling. The ceiling is the estimated future net cash flow from proved oil and gas properties, discounted at 10 percent per year. Any excess is written off as a non-cash expense and may not be reversed in future periods, even though higher oil and gas prices may subsequently increase the ceiling. Future net cash flows are calculated assuming continuation of prices and costs in effect at the time of the calculation, except for changes that are fixed and determinable by existing contracts. Trailing 12-month average prices at the end of each quarter are used in the future net cash flow calculation.

As a result of this accounting calculation, Devon recorded a USD 1.1 billion non-cash asset impairment charge in the third quarter, reducing the carrying value of its oil and gas properties. This impairment charge resulted primarily from the decline of natural gas prices over the past 12 months and is not reflective of the fair value of the company’s assets and has no impact on cash flow or cash balances.

Non-GAAP Reconciliations
Pursuant to regulatory disclosure requirements, Devon is required to reconcile non-GAAP financial measures to the related GAAP information (GAAP refers to generally accepted accounting principles). Net debt and adjusted capitalization are non-GAAP financial measures referenced within this release. Reconciliations of these non-GAAP measures are provided on page 11.