OKLAHOMA CITY–(BUSINESS WIRE)–Devon Energy Corp. (NYSE: DVN) today reported operational and financial results for the second quarter of 2016 and provided guidance for the third quarter and full-year 2016.
Highlights
- Exceeded production expectations in U.S. resource plays
- Raised 2016 production guidance for retained assets by 3 percent
- Reduced lease operating expenses 26 percent year over year
- Improved operating and G&A expense outlook
- Completed asset divestiture program with proceeds totaling $3.2 billion
- Increased E&P capital investment by $200 million in 2016
“Devon Energy’s strategy of operating in North America’s best resource plays, coupled with a focus on delivering best-in-class execution, led to another quarter of excellent operational results,” said Dave Hager, president and CEO. “Production from our U.S. resource plays once again exceeded guidance expectations and we were able to deliver this outperformance with dramatically lower costs. With the cost savings achieved year to date, we are now on pace to reduce operating and G&A expenses by nearly $1 billion in 2016.
“In addition to our strong operating performance, we were able to significantly improve our financial strength over the past several months with the timely completion of our non-core asset divestiture program,” Hager said. “Total divestitures reached $3.2 billion and surpassed the top end of our $2 billion to $3 billion guidance range. The majority of the sales proceeds will be utilized to reduce debt and position us to further accelerate investment in our best-in-class U.S. resource plays, led by the STACK and Delaware Basin.”
Production Exceeds Expectations in U.S. Resource Plays
Devon’s reported net production averaged 644,000 oil-equivalent barrels (Boe) per day during the second quarter of 2016. Of this amount, 545,000 Boe per day was attributable to the Company’s core assets, where investment will be directed going forward. Production from core assets exceeded the mid-point of guidance by 6,000 Boe per day, driven entirely by Devon’s U.S. resource plays.
Within the Company’s U.S. resource plays, production averaged 419,000 Boe per day. This performance was highlighted by strong results from the STACK and Delaware Basin where aggregate production increased 27 percent year over year. Light-oil production from U.S. resource plays, which is Devon’s highest margin product, averaged 110,000 barrels per day. This result exceeded the top end of guidance by 2,000 barrels per day.
In Canada, net oil production from Devon’s heavy-oil projects averaged 121,000 barrels per day in the second quarter. Driven by the industry-leading performance of the Jackfish 3 facility, Canadian oil production increased 24 percent compared to the second quarter of 2015. Scheduled maintenance at the Company’s Jackfish 2 facility curtailed production by 11,000 barrels per day in the quarter.
Retained Midland Assets Enhance 2016 Production Outlook
With the earlier than expected completion of Devon’s asset divestiture program, the Company is updating its third quarter and full-year 2016 production expectations for its retained, go-forward asset base. The most significant change to previous guidance is Devon’s decision to retain select assets in the Midland Basin that were previously categorized as non-core. These legacy Midland Basin assets have extremely low declines and are expected to produce approximately 15,000 Boe per day in the second half of 2016.
Due to the retention of Midland assets and other minor operating interests, Devon is raising the mid-point of its 2016 production guidance from its retained, go-forward asset base by 18,000 Boe per day, or 3 percent. The largest portion of this production raise is attributable to oil, where 2016 mid-point guidance increased by 4 percent or 10,000 barrels per day.
Lease Operating Expenses Decline 26 Percent; Additional Savings Expected
The Company has several cost-reduction initiatives underway that positively impacted second-quarter results. The most significant operating cost savings came from lease operating expenses (LOE), which is Devon’s largest field-level cost. LOE declined 26 percent compared to the second quarter of 2015 to $416 million, and was 5 percent below the low end of guidance. The decrease in LOE was primarily driven by improved power and water-handling infrastructure, declining labor expense and lower supply chain costs.
Due to the operating cost performance achieved year to date and the impact of recently announced asset divestitures, the Company is lowering its full-year 2016 LOE outlook by $150 million to a range of $1.6 billion to $1.7 billion. With this improved outlook, Devon is now on track to reduce LOE and production taxes by nearly $600 million compared to 2015.
G&A Cost Savings Initiatives Ahead of Schedule
Devon also realized substantial general and administrative (G&A) cost savings in the second quarter. G&A expenses totaled $147 million, a 30 percent improvement compared to the second quarter of 2015. The significantly lower overhead costs were driven by reduced personnel expenses.
The Company now anticipates G&A expenses to decline to a range of $600 million to $650 million for the full-year 2016. Combined with reductions in capitalized G&A, Devon projects its total overhead costs to decline by approximately $400 million compared to 2015.
Accelerating Upstream Investment Activity
Devon continued to effectively control capital costs during the second quarter. Devon’s accrued upstream capital spending, which accounts for activity that was incurred during the reporting period, amounted to $221 million in the quarter. This result was $29 million below the low end of the Company’s guidance range.
As previously announced in June, Devon expects its full-year 2016 upstream capital program to range between $1.1 billion and $1.3 billion, an increase of $200 million from previous guidance. The incremental capital will be deployed in the STACK and Delaware Basin, with the potential to add as many as 7 operated rigs between these prolific plays in the second half of 2016. The additional capital investment is expected to deliver incremental production in early 2017.
Second-Quarter 2016 Operations Report
For additional details on Devon’s E&P operations, please refer to the Company’s second-quarter 2016 operations report at www.devonenergy.com. Highlights from the report include:
- Record-setting Meramec oil well brought online
- Successful spacing tests in STACK
- Bone Spring development wells outperform type curve
- Another high-rate well in the Leonard Shale
- Significant free cash flow generation in Eagle Ford
- Jackfish complex production exceeds nameplate capacity by 9 percent
Divestiture Program Complete and Exceeds Expectations
In the second quarter of 2016, Devon announced multiple agreements to monetize $2 billion of non-core upstream assets in the U.S. Several of these transactions have closed and the Company expects the remaining transactions to close in the third quarter. The Company expects to incur minimal cash taxes associated with these divestitures.
Subsequent to quarter end, the Company announced an agreement to sell its 50 percent interest in the Access Pipeline for CAD $1.4 billion, or USD $1.1 billion. This transaction is expected to close in the third quarter of 2016. With the announced sale of Access Pipeline, Devon’s divestiture program is now complete reaching $3.2 billion, exceeding the top end of the Company’s $2 billion to $3 billion guidance range. At least two-thirds of the sales proceeds are expected to be utilized for debt reduction, while the remaining amount will be reinvested in the Company’s U.S. resource plays.
Significant Liquidity and Financial Strength
Devon exited the second quarter with $1.7 billion of cash on hand. Pro-forma for the recent asset sales, cash balances will increase to $4.6 billion and the Company had no borrowings on its $3 billion senior credit facility.
The Company’s consolidated debt was $12.7 billion at the end of the second quarter. Adjusted for asset sales, Devon’s net debt, which excludes non-recourse EnLink obligations, declines to $4.7 billion. The Company’s ownership in EnLink is valued at greater than $3 billion and is expected to generate cash distributions of $270 million in 2016.
Cash Inflow Exceeds $800 Million
In the second quarter of 2016 Devon had a reported net loss of $1.6 billion, or $3.04 per share. Adjusting for items that securities analysts typically exclude from their published estimates, Devon’s core earnings totaled $33 million, or $0.06 per share.
Adjusted earnings before interest, taxes, depreciation and amortization (EBITDA) reached $649 million in the second quarter of 2016. The closing of the Company’s non-core Mississippian assets added approximately $200 million of additional cash flow in the second quarter of 2016, bringing cash inflows to more than $800 million.
Non-GAAP Reconciliations
Pursuant to regulatory disclosure requirements, Devon is required to reconcile non-GAAP (generally accepted accounting principles) financial measures to the related GAAP information. Net debt, adjusted net debt, core earnings, core earnings per share and adjusted EBITDA referenced within the commentary of this release are non-GAAP financial measures. Reconciliations of these non-GAAP measures are provided within the tables of this release.
Conference Call Webcast and Supplemental Earnings Materials
Please note that as soon as practicable today, Devon will post an operations report to its website at www.devonenergy.com. The Company’s second-quarter conference call will be held at 10 a.m. Central (11 a.m. Eastern) on Wednesday, Aug. 3, 2016, and will serve primarily as a forum for analyst and investor questions and answers.
Forward-Looking Statements
This press release includes “forward-looking statements” as defined by the Securities and Exchange Commission (SEC). Such statements include those concerning strategic plans, expectations and objectives for future operations, and are often identified by use of the words “expects,” “believes,” “will,” “would,” “could,” “forecasts,” “projections,” “estimates,” “plans,” “expectations,” “targets,” “opportunities,” “potential,” “anticipates,” “outlook” and other similar terminology. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the Company expects, believes or anticipates will or may occur in the future are forward-looking statements. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company. Statements regarding our business and operations are subject to all of the risks and uncertainties normally incident to the exploration for and development and production of oil and gas. These risks include, but are not limited to: the volatility of oil, gas and NGL prices, including the currently depressed commodity price environment; uncertainties inherent in estimating oil, gas and NGL reserves; the extent to which we are successful in acquiring and discovering additional reserves; the uncertainties, costs and risks involved in exploration and development activities; risks related to our hedging activities; counterparty credit risks; regulatory restrictions, compliance costs and other risks relating to governmental regulation, including with respect to environmental matters; risks relating to our indebtedness; our ability to successfully complete mergers, acquisitions and divestitures; the extent to which insurance covers any losses we may experience; our limited control over third parties who operate our oil and gas properties; midstream capacity constraints and potential interruptions in production; competition for leases, materials, people and capital; cyberattacks targeting our systems and infrastructure; and any of the other risks and uncertainties identified in our Form 10-K and our other filings with the SEC. Investors are cautioned that any such statements are not guarantees of future performance and that actual results or developments may differ materially from those projected in the forward-looking statements. The forward-looking statements in this press release are made as of the date of this press release, even if subsequently made available by Devon on its website or otherwise. Devon does not undertake any obligation to update the forward-looking statements as a result of new information, future events or otherwise.
The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves that meet the SEC’s definitions for such terms, and price and cost sensitivities for such reserves, and prohibits disclosure of resources that do not constitute such reserves. This release may contain certain terms, such as resource potential and exploration target size. These estimates are by their nature more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of being actually realized. The SEC guidelines strictly prohibit us from including these estimates in filings with the SEC. Investors are urged to consider closely the disclosure in our Form 10-K, available at www.devonenergy.com. You can also obtain this form from the SEC by calling 1-800-SEC-0330 or from the SEC’s website at www.sec.gov.
About Devon Energy
Devon Energy is a leading independent energy company engaged in finding and producing oil and natural gas. Based in Oklahoma City and included in the S&P 500, Devon operates in several of the most prolific oil and natural gas plays in the U.S. and Canada with an emphasis on a balanced portfolio. The Company is the second-largest oil producer among North American onshore independents. For more information, please visit www.devonenergy.com.
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DEVON ENERGY CORPORATION |
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| FINANCIAL AND OPERATIONAL INFORMATION | ||||||||||||||||
| Quarter Ended | Six Months Ended | |||||||||||||||
| PRODUCTION NET OF ROYALTIES | June 30, | June 30, | ||||||||||||||
| 2016 | 2015 | 2016 | 2015 | |||||||||||||
| Oil and bitumen (MBbls/d) | ||||||||||||||||
| U. S. – Core | 110 | 131 | 119 | 129 | ||||||||||||
| Heavy Oil | 121 | 98 | 124 | 101 | ||||||||||||
| Core assets | 231 | 229 | 243 | 230 | ||||||||||||
| Other | 28 | 41 | 29 | 41 | ||||||||||||
| Total | 259 | 270 | 272 | 271 | ||||||||||||
| Natural gas liquids (MBbls/d) | ||||||||||||||||
| U. S. – Core | 103 | 100 | 105 | 102 | ||||||||||||
| Other | 28 | 34 | 29 | 34 | ||||||||||||
| Total | 131 | 134 | 134 | 136 | ||||||||||||
| Gas (MMcf/d) | ||||||||||||||||
| U. S. – Core | 1,239 | 1,288 | 1,267 | 1,296 | ||||||||||||
| Heavy Oil | 28 | 20 | 22 | 24 | ||||||||||||
| Core assets | 1,267 | 1,308 | 1,289 | 1,320 | ||||||||||||
| Other | 260 | 319 | 265 | 316 | ||||||||||||
| Total | 1,527 | 1,627 | 1,554 | 1,636 | ||||||||||||
| Oil equivalent (MBoe/d) | ||||||||||||||||
| U. S. – Core | 419 | 446 | 436 | 448 | ||||||||||||
| Heavy Oil | 126 | 101 | 127 | 105 | ||||||||||||
| Core assets | 545 | 547 | 563 | 553 | ||||||||||||
| Other | 99 | 127 | 102 | 126 | ||||||||||||
| Total | 644 | 674 | 665 | 679 | ||||||||||||
| KEY OPERATING STATISTICS BY REGION | ||||||||||||
| Quarter Ended June 30, 2016 | ||||||||||||
| Avg. Production | Gross Wells | Operated Rigs at | ||||||||||
| (MBoe/d) | Drilled | June 30, 2016 | ||||||||||
| STACK | 91 | 24 | 2 | |||||||||
| Delaware Basin | 65 | 14 | — | |||||||||
| Eagle Ford | 75 | 6 | — | |||||||||
| Rockies Oil | 21 | — | — | |||||||||
| Heavy Oil | 126 | — | — | |||||||||
| Barnett Shale | 167 | — | — | |||||||||
| Core assets | 545 | 44 | 2 | |||||||||
| PRODUCTION TREND | 2015 | 2016 | ||||||||||||||||||
| Quarter 2 | Quarter 3 | Quarter 4 | Quarter 1 | Quarter 2 | ||||||||||||||||
| Oil and bitumen (MBbls/d) | ||||||||||||||||||||
| STACK | 6 | 6 | 7 | 14 | 17 | |||||||||||||||
| Delaware Basin | 41 | 41 | 42 | 38 | 36 | |||||||||||||||
| Eagle Ford | 67 | 62 | 60 | 59 | 41 | |||||||||||||||
| Rockies Oil | 16 | 16 | 16 | 17 | 15 | |||||||||||||||
| Heavy Oil | 98 | 121 | 121 | 126 | 121 | |||||||||||||||
| Barnett Shale | 1 | 1 | 1 | 1 | 1 | |||||||||||||||
| Core assets | 229 | 247 | 247 | 255 | 231 | |||||||||||||||
| Other | 41 | 35 | 31 | 30 | 28 | |||||||||||||||
| Total | 270 | 282 | 278 | 285 | 259 | |||||||||||||||
| Natural gas liquids (MBbls/d) | ||||||||||||||||||||
| STACK | 16 | 22 | 23 | 29 | 29 | |||||||||||||||
| Delaware Basin | 10 | 8 | 11 | 12 | 13 | |||||||||||||||
| Eagle Ford | 24 | 26 | 27 | 24 | 17 | |||||||||||||||
| Rockies Oil | 1 | 2 | 1 | 1 | 1 | |||||||||||||||
| Barnett Shale | 49 | 44 | 46 | 42 | 43 | |||||||||||||||
| Core assets | 100 | 102 | 108 | 108 | 103 | |||||||||||||||
| Other | 34 | 32 | 31 | 29 | 28 | |||||||||||||||
| Total | 134 | 134 | 139 | 137 | 131 | |||||||||||||||
| Gas (MMcf/d) | ||||||||||||||||||||
| STACK | 221 | 216 | 235 | 286 | 267 | |||||||||||||||
| Delaware Basin | 75 | 70 | 82 | 84 | 99 | |||||||||||||||
| Eagle Ford | 146 | 154 | 151 | 144 | 103 | |||||||||||||||
| Rockies Oil | 41 | 41 | 38 | 32 | 31 | |||||||||||||||
| Heavy Oil | 20 | 16 | 24 | 15 | 28 | |||||||||||||||
| Barnett Shale | 805 | 788 | 768 | 749 | 739 | |||||||||||||||
| Core assets | 1,308 | 1,285 | 1,298 | 1,310 | 1,267 | |||||||||||||||
| Other | 319 | 301 | 285 | 271 | 260 | |||||||||||||||
| Total | 1,627 | 1,586 | 1,583 | 1,581 | 1,527 | |||||||||||||||
| Oil equivalent (MBoe/d) | ||||||||||||||||||||
| STACK | 59 | 64 | 70 | 91 | 91 | |||||||||||||||
| Delaware Basin | 64 | 61 | 66 | 63 | 65 | |||||||||||||||
| Eagle Ford | 114 | 113 | 111 | 107 | 75 | |||||||||||||||
| Rockies Oil | 24 | 25 | 23 | 23 | 21 | |||||||||||||||
| Heavy Oil | 101 | 124 | 126 | 129 | 126 | |||||||||||||||
| Barnett Shale | 185 | 176 | 175 | 168 | 167 | |||||||||||||||
| Core assets | 547 | 563 | 571 | 581 | 545 | |||||||||||||||
| Other | 127 | 117 | 110 | 104 | 99 | |||||||||||||||
| Total | 674 | 680 | 681 | 685 | 644 | |||||||||||||||
| BENCHMARK PRICES | |||||||||||||||||||||||
| (average prices) | Quarter 2 | June YTD | |||||||||||||||||||||
| 2016 | 2015 | 2016 | 2015 | ||||||||||||||||||||
| Oil ($/Bbl) – West Texas Intermediate (Cushing) | $ | 45.54 | $ | 57.78 | $ | 39.60 | $ | 53.33 | |||||||||||||||
| Natural Gas ($/Mcf) – Henry Hub | $ | 1.95 | $ | 2.65 | $ | 2.02 | $ | 2.82 | |||||||||||||||
| REALIZED PRICES | Quarter Ended June 30, 2016 | ||||||||||||||||||||||
| Oil /Bitumen | NGL | Gas | Total | ||||||||||||||||||||
| (Per Bbl) | (Per Bbl) | (Per Mcf) | (Per Boe) | ||||||||||||||||||||
| United States | $ | 41.56 | $ | 10.14 | $ | 1.40 | $ | 17.68 | |||||||||||||||
| Canada | $ | 22.53 | N/M | N/M | $ | 21.85 | |||||||||||||||||
| Realized price without hedges | $ | 32.64 | $ | 10.14 | $ | 1.40 | $ | 18.50 | |||||||||||||||
| Cash settlements | $ | (2.57 | ) | $ | (0.25 | ) | $ | 0.24 | $ | (0.53 | ) | ||||||||||||
| Realized price, including cash settlements | $ | 30.07 | $ | 9.89 | $ | 1.64 | $ | 17.97 | |||||||||||||||
| Quarter Ended June 30, 2015 | |||||||||||||||||||||||
| Oil /Bitumen | NGL | Gas | Total | ||||||||||||||||||||
| (Per Bbl) | (Per Bbl) | (Per Mcf) | (Per Boe) | ||||||||||||||||||||
| United States | $ | 52.52 | $ | 10.31 | $ | 2.13 | $ | 24.18 | |||||||||||||||
| Canada | $ | 36.49 | N/M | N/M | $ | 35.33 | |||||||||||||||||
| Realized price without hedges | $ | 46.69 | $ | 10.31 | $ | 2.13 | $ | 25.86 | |||||||||||||||
| Cash settlements | $ | 16.08 | $ | — | $ | 0.58 | $ | 7.83 | |||||||||||||||
| Realized price, including cash settlements | $ | 62.77 | $ | 10.31 | $ | 2.71 | $ | 33.69 | |||||||||||||||
| Six Months Ended June 30, 2016 | |||||||||||||||||||||||
| Oil /Bitumen | NGL | Gas | Total | ||||||||||||||||||||
| (Per Bbl) | (Per Bbl) | (Per Mcf) | (Per Boe) | ||||||||||||||||||||
| United States | $ | 34.70 | $ | 8.46 | $ | 1.47 | $ | 15.89 | |||||||||||||||
| Canada | $ | 15.71 | N/M | N/M | $ | 15.33 | |||||||||||||||||
| Realized price without hedges | $ | 26.05 | $ | 8.46 | $ | 1.47 | $ | 15.78 | |||||||||||||||
| Cash settlements | $ | (1.23 | ) | $ | (0.13 | ) | $ | 0.18 | $ | (0.10 | ) | ||||||||||||
| Realized price, including cash settlements | $ | 24.82 | $ | 8.33 | $ | 1.65 | $ | 15.68 | |||||||||||||||
| Six Months Ended June 30, 2015 | |||||||||||||||||||||||
| Oil /Bitumen | NGL | Gas | Total | ||||||||||||||||||||
| (Per Bbl) | (Per Bbl) | (Per Mcf) | (Per Boe) | ||||||||||||||||||||
| United States | $ | 47.74 | $ | 9.85 | $ | 2.29 | $ | 22.93 | |||||||||||||||
| Canada | $ | 29.51 | N/M | N/M | $ | 28.56 | |||||||||||||||||
| Realized price without hedges | $ | 40.94 | $ | 9.85 | $ | 2.29 | $ | 23.80 | |||||||||||||||
| Cash settlements | $ | 18.59 | $ | — | $ | 0.55 | $ | 8.72 | |||||||||||||||
| Realized price, including cash settlements | $ | 59.53 | $ | 9.85 | $ | 2.84 | $ | 32.52 | |||||||||||||||
| CONSOLIDATED STATEMENTS OF EARNINGS | ||||||||||||||||||||||||
| (in millions, except per share amounts) | Quarter Ended | Six Months Ended | ||||||||||||||||||||||
| June 30, | June 30, | |||||||||||||||||||||||
| 2016 | 2015 | 2016 | 2015 | |||||||||||||||||||||
| Oil, gas and NGL sales | $ | 1,085 | $ | 1,587 | $ | 1,910 | $ | 2,926 | ||||||||||||||||
| Oil, gas and NGL derivatives | (142 | ) | (282 | ) | (109 | ) | 12 | |||||||||||||||||
| Marketing and midstream revenues | 1,545 | 2,088 | 2,813 | 3,720 | ||||||||||||||||||||
| Total operating revenues | 2,488 | 3,393 | 4,614 | 6,658 | ||||||||||||||||||||
| Lease operating expenses | 416 | 562 | 860 | 1,115 | ||||||||||||||||||||
| Marketing and midstream operating expenses | 1,338 | 1,863 | 2,404 | 3,302 | ||||||||||||||||||||
| General and administrative expenses | 147 | 212 | 341 | 463 | ||||||||||||||||||||
| Production and property taxes | 75 | 116 | 153 | 224 | ||||||||||||||||||||
| Depreciation, depletion and amortization | 484 | 814 | 1,026 | 1,744 | ||||||||||||||||||||
| Asset impairments | 1,497 | 4,168 | 4,532 | 9,628 | ||||||||||||||||||||
| Restructuring and transaction costs | 24 | — | 271 | — | ||||||||||||||||||||
| Other operating items | 4 | 21 | 24 | 40 | ||||||||||||||||||||
| Total operating expenses | 3,985 | 7,756 | 9,611 | 16,516 | ||||||||||||||||||||
| Operating loss | (1,497 | ) | (4,363 | ) | (4,997 | ) | (9,858 | ) | ||||||||||||||||
| Net financing costs | 163 | 125 | 327 | 242 | ||||||||||||||||||||
| Other nonoperating items | 85 | (9 | ) | 106 | 3 | |||||||||||||||||||
| Loss before income taxes | (1,745 | ) | (4,479 | ) | (5,430 | ) | (10,103 | ) | ||||||||||||||||
| Income tax benefit | (182 | ) | (1,686 | ) | (399 | ) | (3,721 | ) | ||||||||||||||||
| Net loss | (1,563 | ) | (2,793 | ) | (5,031 | ) | (6,382 | ) | ||||||||||||||||
| Net earnings (loss) attributable to noncontrolling interests | 7 | 23 | (405 | ) | 33 | |||||||||||||||||||
| Net loss attributable to Devon | $ | (1,570 | ) | $ | (2,816 | ) | $ | (4,626 | ) | $ | (6,415 | ) | ||||||||||||
| Net loss per share attributable to Devon: | ||||||||||||||||||||||||
| Basic | $ | (3.04 | ) | $ | (6.94 | ) | $ | (9.33 | ) | $ | (15.81 | ) | ||||||||||||
| Diluted | $ | (3.04 | ) | $ | (6.94 | ) | $ | (9.33 | ) | $ | (15.81 | ) | ||||||||||||
| Weighted average common shares outstanding: | ||||||||||||||||||||||||
| Basic | 524 | 411 | 502 | 411 | ||||||||||||||||||||
| Diluted | 524 | 411 | 502 | 411 | ||||||||||||||||||||
| CONSOLIDATED STATEMENTS OF CASH FLOWS | ||||||||||||||||||||||||
| (in millions) | ||||||||||||||||||||||||
| Quarter Ended | Six Months Ended | |||||||||||||||||||||||
| June 30, | June 30, | |||||||||||||||||||||||
| 2016 | 2015 | 2016 | 2015 | |||||||||||||||||||||
| Cash flows from operating activities: | ||||||||||||||||||||||||
| Net loss | $ | (1,563 | ) | $ | (2,793 | ) | $ | (5,031 | ) | $ | (6,382 | ) | ||||||||||||
| Adjustments to reconcile net loss to net cash from operating activities: | ||||||||||||||||||||||||
| Depreciation, depletion and amortization | 484 | 814 | 1,026 | 1,744 | ||||||||||||||||||||
| Asset impairments | 1,497 | 4,168 | 4,532 | 9,628 | ||||||||||||||||||||
| Deferred income tax benefit | (179 | ) | (1,593 | ) | (386 | ) | (3,640 | ) | ||||||||||||||||
| Derivatives and other financial instruments | 223 | 305 | 417 | (125 | ) | |||||||||||||||||||
| Cash settlements on derivatives and financial instruments | (44 | ) | 464 | (148 | ) | 1,183 | ||||||||||||||||||
| Other noncash charges | 88 | 41 | 21 | 266 | ||||||||||||||||||||
| Net change in working capital | (153 | ) | (189 | ) | 45 | 26 | ||||||||||||||||||
| Change in long-term other assets | (40 | ) | 18 | 13 | 159 | |||||||||||||||||||
| Change in long-term other liabilities | 22 | (134 | ) | (5 | ) | (110 | ) | |||||||||||||||||
| Net cash from operating activities | 335 | 1,101 | 484 | 2,749 | ||||||||||||||||||||
| Cash flows from investing activities: | ||||||||||||||||||||||||
| Capital expenditures | (489 | ) | (1,432 | ) | (1,238 | ) | (3,149 | ) | ||||||||||||||||
| Acquisitions of property, equipment and businesses | (11 | ) | (13 | ) | (1,638 | ) | (417 | ) | ||||||||||||||||
| Divestitures of property and equipment | 191 | 6 | 209 | 8 | ||||||||||||||||||||
| Other | (26 | ) | (8 | ) | (27 | ) | (5 | ) | ||||||||||||||||
| Net cash from investing activities | (335 | ) | (1,447 | ) | (2,694 | ) | (3,563 | ) | ||||||||||||||||
| Cash flows from financing activities: | ||||||||||||||||||||||||
| Borrowings of long-term debt, net of issuance costs | 450 | 2,094 | 846 | 3,051 | ||||||||||||||||||||
| Repayments of long-term debt | (290 | ) | (1,034 | ) | (549 | ) | (1,521 | ) | ||||||||||||||||
| Net short-term repayments | — | (778 | ) | (626 | ) | (763 | ) | |||||||||||||||||
| Issuance of common stock | — | — | 1,469 | — | ||||||||||||||||||||
| Sale of subsidiary units | — | 85 | — | 654 | ||||||||||||||||||||
| Issuance of subsidiary units | 49 | 2 | 776 | 4 | ||||||||||||||||||||
| Dividends paid on common stock | (33 | ) | (98 | ) | (158 | ) | (197 | ) | ||||||||||||||||
| Distributions to noncontrolling interests | (74 | ) | (65 | ) | (147 | ) | (118 | ) | ||||||||||||||||
| Other | (2 | ) | 4 | (2 | ) | (8 | ) | |||||||||||||||||
| Net cash from financing activities | 100 | 210 | 1,609 | 1,102 | ||||||||||||||||||||
| Effect of exchange rate changes on cash | (12 | ) | 3 | 14 | (43 | ) | ||||||||||||||||||
| Net change in cash and cash equivalents | 88 | (133 | ) | (587 | ) | 245 | ||||||||||||||||||
| Cash and cash equivalents at beginning of period | 1,635 | 1,858 | 2,310 | 1,480 | ||||||||||||||||||||
| Cash and cash equivalents at end of period | $ | 1,723 | $ | 1,725 | $ | 1,723 | $ | 1,725 | ||||||||||||||||
| CONSOLIDATED BALANCE SHEETS | ||||||||||||
| (in millions) | June 30, | December 31, | ||||||||||
| 2016 | 2015 | |||||||||||
| Current assets: | ||||||||||||
| Cash and cash equivalents | $ | 1,723 | $ | 2,310 | ||||||||
| Accounts receivable | 1,167 | 1,105 | ||||||||||
| Assets held for sale | 728 | — | ||||||||||
| Other current assets | 364 | 606 | ||||||||||
| Total current assets | 3,982 | 4,021 | ||||||||||
| Property and equipment, at cost: | ||||||||||||
| Oil and gas, based on full cost accounting: | ||||||||||||
| Subject to amortization | 80,066 | 78,190 | ||||||||||
| Not subject to amortization | 3,798 | 2,584 | ||||||||||
| Total oil and gas | 83,864 | 80,774 | ||||||||||
| Midstream and other | 10,243 | 10,380 | ||||||||||
| Total property and equipment, at cost | 94,107 | 91,154 | ||||||||||
| Less accumulated depreciation, depletion and amortization | (77,292 | ) | (72,086 | ) | ||||||||
| Property and equipment, net | 16,815 | 19,068 | ||||||||||
| Goodwill | 4,159 | 5,032 | ||||||||||
| Other long-term assets | 2,288 | 1,330 | ||||||||||
| Total assets | $ | 27,244 | $ | 29,451 | ||||||||
| Current liabilities: | ||||||||||||
| Accounts payable | $ | 545 | $ | 906 | ||||||||
| Revenues and royalties payable | 819 | 763 | ||||||||||
| Short-term debt | 350 | 976 | ||||||||||
| Liabilities held for sale | 205 | — | ||||||||||
| Other current liabilities | 1,010 | 650 | ||||||||||
| Total current liabilities | 2,929 | 3,295 | ||||||||||
| Long-term debt | 12,357 | 12,056 | ||||||||||
| Asset retirement obligations | 1,473 | 1,370 | ||||||||||
| Other long-term liabilities | 1,011 | 853 | ||||||||||
| Deferred income taxes | 555 | 888 | ||||||||||
| Stockholders’ equity: | ||||||||||||
| Common stock | 52 | 42 | ||||||||||
| Additional paid-in capital | 7,500 | 4,996 | ||||||||||
| Retained earnings (accumulated deficit) |
(2,970 |
) |
1,781 | |||||||||
| Accumulated other comprehensive earnings | 265 | 230 | ||||||||||
| Total stockholders’ equity attributable to Devon | 4,847 | 7,049 | ||||||||||
| Noncontrolling interests | 4,072 | 3,940 | ||||||||||
| Total stockholders’ equity | 8,919 | 10,989 | ||||||||||
| Total liabilities and stockholders’ equity | $ | 27,244 | $ | 29,451 | ||||||||
| Common shares outstanding | 524 | 418 | ||||||||||
| CONSOLIDATING STATEMENTS OF OPERATIONS | ||||||||||||||||||||||||
| (in millions) | ||||||||||||||||||||||||
| Quarter Ended June 30, 2016 | ||||||||||||||||||||||||
|
Devon U.S. |
EnLink | Eliminations | Total | |||||||||||||||||||||
| Oil, gas and NGL sales | $ | 1,085 | $ | — | $ | — | $ | 1,085 | ||||||||||||||||
| Oil, gas and NGL derivatives | (142 | ) | — | — | (142 | ) | ||||||||||||||||||
| Marketing and midstream revenues | 688 | 1,033 | (176 | ) | 1,545 | |||||||||||||||||||
| Total operating revenues | 1,631 | 1,033 | (176 | ) | 2,488 | |||||||||||||||||||
| Lease operating expenses | 416 | — | — | 416 | ||||||||||||||||||||
| Marketing and midstream operating expenses | 692 | 822 | (176 | ) | 1,338 | |||||||||||||||||||
| General and administrative expenses | 118 | 29 | — | 147 | ||||||||||||||||||||
| Production and property taxes | 64 | 11 | — | 75 | ||||||||||||||||||||
| Depreciation, depletion and amortization | 359 | 125 | — | 484 | ||||||||||||||||||||
| Asset impairments | 1,497 | — | — | 1,497 | ||||||||||||||||||||
| Restructuring and transaction costs | 23 | 1 | — | 24 | ||||||||||||||||||||
| Other operating items | 4 | — | — | 4 | ||||||||||||||||||||
| Total operating expenses | 3,173 | 988 | (176 | ) | 3,985 | |||||||||||||||||||
| Operating earnings (loss) | (1,542 | ) | 45 | — | (1,497 | ) | ||||||||||||||||||
| Net financing costs | 117 | 46 | — | 163 | ||||||||||||||||||||
| Other nonoperating items | 85 | — | — | 85 | ||||||||||||||||||||
| Loss before income taxes | (1,744 | ) | (1 | ) | — | (1,745 | ) | |||||||||||||||||
| Income tax benefit | (180 | ) | (2 | ) | — | (182 | ) | |||||||||||||||||
| Net earnings (loss) | (1,564 | ) | 1 | — | (1,563 | ) | ||||||||||||||||||
| Net earnings attributable to noncontrolling interests | 1 | 6 | — | 7 | ||||||||||||||||||||
| Net loss attributable to Devon | $ | (1,565 | ) | $ | (5 | ) | $ | — | $ | (1,570 | ) | |||||||||||||
Contacts
Devon Energy Corporation
Investor Contacts
Howard Thill, 405-552-3693
Scott Coody, 405-552-4735
Chris Carr, 405-228-2496
Media Contact
John Porretto, 405-228-7506
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